[Title 40 CFR ]
[Code of Federal Regulations (annual edition) - July 1, 2023 Edition]
[From the U.S. Government Publishing Office]



[[Page i]]

          

                                     Title 40

                             Protection of Environment


                            ________________________

                                Part 1060 to End

                         Revised as of July 1, 2023

          Containing a codification of documents of general 
          applicability and future effect

          As of July 1, 2023
                    Published by the Office of the Federal Register 
                    National Archives and Records Administration as a 
                    Special Edition of the Federal Register

[[Page ii]]

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                            Table of Contents



                                                                    Page
  Explanation.................................................       v

  Title 40:
          Chapter I--Environmental Protection Agency 
          (Continued)                                                3
          Chapter IV--Environmental Protection Agency and 
          Department of Justice                                    635
          Chapter V--Council on Environmental Quality              643
          Chapter VI--Chemical Safety and Hazard Investigation 
          Board                                                    695
          Chapter VII--Environmental Protection Agency and 
          Department of Defense; Uniform National Discharge 
          Standards for Vessels of the Armed Forces                737
          Chapter VIII--Gulf Coast Ecosystem Restoration 
          Council                                                  757
          Chapter IX--Federal Permitting Improvement Steering 
          Council                                                  779
  Finding Aids:
      Table of CFR Titles and Chapters........................     785
      Alphabetical List of Agencies Appearing in the CFR......     805
      List of CFR Sections Affected...........................     815

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                     ----------------------------

                     Cite this Code: CFR
                     To cite the regulations in 
                       this volume use title, 
                       part and section number. 
                       Thus, 40 CFR 1060.1 refers 
                       to title 40, part 1060, 
                       section 1.

                     ----------------------------

[[Page v]]



                               EXPLANATION

    The Code of Federal Regulations is a codification of the general and 
permanent rules published in the Federal Register by the Executive 
departments and agencies of the Federal Government. The Code is divided 
into 50 titles which represent broad areas subject to Federal 
regulation. Each title is divided into chapters which usually bear the 
name of the issuing agency. Each chapter is further subdivided into 
parts covering specific regulatory areas.
    Each volume of the Code is revised at least once each calendar year 
and issued on a quarterly basis approximately as follows:

Title 1 through Title 16.................................as of January 1
Title 17 through Title 27..................................as of April 1
Title 28 through Title 41...................................as of July 1
Title 42 through Title 50................................as of October 1

    The appropriate revision date is printed on the cover of each 
volume.

LEGAL STATUS

    The contents of the Federal Register are required to be judicially 
noticed (44 U.S.C. 1507). The Code of Federal Regulations is prima facie 
evidence of the text of the original documents (44 U.S.C. 1510).

HOW TO USE THE CODE OF FEDERAL REGULATIONS

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EFFECTIVE AND EXPIRATION DATES

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OMB CONTROL NUMBERS

    The Paperwork Reduction Act of 1980 (Pub. L. 96-511) requires 
Federal agencies to display an OMB control number with their information 
collection request.

[[Page vi]]

Many agencies have begun publishing numerous OMB control numbers as 
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PAST PROVISIONS OF THE CODE

    Provisions of the Code that are no longer in force and effect as of 
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for 1949-1963, 1964-1972, 1973-1985, and 1986-2000.

``[RESERVED]'' TERMINOLOGY

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not dropped in error.

INCORPORATION BY REFERENCE

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established by statute and allows Federal agencies to meet the 
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This material, like any other properly issued regulation, has the force 
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    An index to the text of ``Title 3--The President'' is carried within 
that volume.

[[Page vii]]

    The Federal Register Index is issued monthly in cumulative form. 
This index is based on a consolidation of the ``Contents'' entries in 
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the revision dates of the 50 CFR titles.

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in the Code of Federal Regulations.

INQUIRIES

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    Oliver A. Potts,
    Director,
    Office of the Federal Register
    July 1, 2023







[[Page ix]]



                               THIS TITLE

    Title 40--Protection of Environment is composed of thirty-seven 
volumes. The parts in these volumes are arranged in the following order: 
Parts 1-49, parts 50-51, part 52 (52.01-52.1018), part 52 (52.1019-
52.2019), part 52 (52.2020-end of part 52), parts 53-59, part 60 (60.1-
60.499), part 60 (60.500-end of part 60, sections), part 60 
(Appendices), parts 61-62, part 63 (63.1-63.599), part 63 (63.600-
63.1199), part 63 (63.1200-63.1439), part 63 (63.1440-63.6175), part 63 
(63.6580-63.8830), part 63 (63.8980-end of part 63), parts 64-71, parts 
72-79, part 80, part 81, parts 82-84, parts 85-96, parts 97-99, parts 
100-135, parts 136-149, parts 150-189, parts 190-259, parts 260-265, 
parts 266-299, parts 300-399, parts 400-424, parts 425-699, parts 700-
722, parts 723-789, parts 790-999, parts 1000-1059, and part 1060 to 
end. The contents of these volumes represent all current regulations 
codified under this title of the CFR as of July 1, 2023.

    Chapter I--Environmental Protection Agency appears in all thirty-
seven volumes. OMB control numbers for title 40 appear in Sec.  9.1 of 
this chapter.

    Chapters IV-IX--Regulations issued by the Environmental Protection 
Agency and Department of Justice, Council on Environmental Quality, 
Chemical Safety and Hazard Investigation Board, Environmental Protection 
Agency and Department of Defense; Uniform National Discharge Standards 
for Vessels of the Armed Forces, Gulf Coast Ecosystem Restoration 
Council, and the Federal Permitting Improvement Steering Council appear 
in volume thirty-seven.

    For this volume, Michele Bugenhagen was Chief Editor. The Code of 
Federal Regulations publication program is under the direction of John 
Hyrum Martinez, assisted by Stephen J. Frattini.

[[Page 1]]



                   TITLE 40--PROTECTION OF ENVIRONMENT




                  (This book contains part 1060 to end)

  --------------------------------------------------------------------
                                                                    Part

chapter i--Environmental Protection Agency (Continued)......        1060

chapter iv--Environmental Protection Agency and Department 
  of Justice................................................        1400

chapter v--Council on Environmental Quality.................        1500

chapter vi--Chemical Safety and Hazard Investigation Board..        1600

chapter vii--Environmental Protection Agency and Department 
  of Defense; Uniform National Discharge Standards for 
  Vessels of the Armed Forces...............................        1700

chapter viii--Gulf Coast Ecosystem Restoration Council......        1800

chapter ix--Federal Permitting Improvement Steering Council.        1900

[[Page 3]]



         CHAPTER I--ENVIRONMENTAL PROTECTION AGENCY (CONTINUED)




  --------------------------------------------------------------------


  Editorial Note: Nomenclature changes to chapter I appear at 65 FR 
47324, 47325, Aug. 2, 2000, and 66 FR 34375, 34376, June 28, 2001.

                  SUBCHAPTER U--AIR POLLUTION CONTROLS
Part                                                                Page
1060            Control of evaporative emissions from new 
                    and in-use nonroad and stationary 
                    equipment...............................           5
1065            Engine-testing procedures...................          46
1066            Vehicle-testing procedures..................         331
1068            General compliance provisions for highway, 
                    stationary, and nonroad programs........         433
1074            Preemption of state standards and procedures 
                    for waiver of federal preemption for 
                    nonroad engines and nonroad vehicles....         511
1075-1089

 [Reserved]

1090            Regulation of fuels, fuel additives, and 
                    regulated blendstocks...................         513
1091-1099

 [Reserved]

[[Page 5]]



                   SUBCHAPTER U_AIR POLLUTION CONTROLS





PART 1060_CONTROL OF EVAPORATIVE EMISSIONS FROM NEW 
AND IN-USE NONROAD AND STATIONARY EQUIPMENT--Table of Contents



                  Subpart A_Overview and Applicability

Sec.
1060.1 Which products are subject to this part's requirements?
1060.5 Do the requirements of this part apply to me?
1060.10 How is this part organized?
1060.15 Do any other CFR parts apply to me?
1060.30 Submission of information.

          Subpart B_Emission Standards and Related Requirements

1060.101 What evaporative emission requirements apply under this part?
1060.102 What permeation emission control requirements apply for fuel 
          lines?
1060.103 What permeation emission control requirements apply for fuel 
          tanks?
1060.104 What running loss emission control requirements apply?
1060.105 What diurnal requirements apply for equipment?
1060.120 What emission-related warranty requirements apply?
1060.125 What maintenance instructions must I give to buyers?
1060.130 What installation instructions must I give to equipment 
          manufacturers?
1060.135 How must I label and identify the engines and equipment I 
          produce?
1060.137 How must I label and identify the fuel-system components I 
          produce?

                 Subpart C_Certifying Emission Families

1060.201 What are the general requirements for obtaining a certificate 
          of conformity?
1060.202 What are the certification requirements related to the general 
          standards in Sec.  1060.101?
1060.205 What must I include in my application?
1060.210 What records should equipment manufacturers keep if they do not 
          apply for certification?
1060.225 How do I amend my application for certification?
1060.230 How do I select emission families?
1060.235 What testing requirements apply for certification?
1060.240 How do I demonstrate that my emission family complies with 
          evaporative emission standards?
1060.250 What records must I keep?
1060.255 What decisions may EPA make regarding a certificate of 
          conformity?

                Subpart D_Production Verification Testing

1060.301 Manufacturer testing.
1060.310 Supplying products to EPA for testing.

                        Subpart E_In-Use Testing

1060.401 General Provisions.

                        Subpart F_Test Procedures

1060.501 General testing provisions.
1060.505 Other procedures.
1060.510 How do I test EPA Low-Emission Fuel Lines for permeation 
          emissions?
1060.515 How do I test EPA Nonroad Fuel Lines and EPA Cold-Weather Fuel 
          Lines for permeation emissions?
1060.520 How do I test fuel tanks for permeation emissions?
1060.521 How do I test fuel caps for permeation emissions?
1060.525 How do I test fuel systems for diurnal emissions?

                 Subpart G_Special Compliance Provisions

1060.601 How do the prohibitions of 40 CFR 1068.101 apply with respect 
          to the requirements of this part?
1060.605 Exemptions from evaporative emission standards.
1060.610 Temporary exemptions for manufacturing and assembling equipment 
          and fuel-system components.

          Subpart H_Averaging, Banking, and Trading Provisions

1060.701 Applicability.
1060.705 How do I certify components to an emission level other than the 
          standard under this part or use such components in my 
          equipment?

          Subpart I_Definitions and Other Reference Information

1060.801 What definitions apply to this part?
1060.805 What symbols, acronyms, and abbreviations does this part use?
1060.810 What materials does this part reference?
1060.815 What provisions apply to confidential information?
1060.820 How do I request a hearing?
1060.825 What reporting and recordkeeping requirements apply under this 
          part?

    Authority: 42 U.S.C. 7401-7671q.

[[Page 6]]


    Source: 73 FR 59298, Oct. 8, 2008, unless otherwise noted.



                  Subpart A_Overview and Applicability



Sec.  1060.1  Which products are subject to this part's requirements?

    (a) The standards and other requirements in this part 1060 apply to 
the fuel lines, fuel tanks, couplings and fittings, and fuel caps used 
or intended to be used in the following categories of new engines and 
equipment that are fueled with a volatile liquid fuel (such as gasoline, 
but not including diesel fuel), and to the equipment in which these 
components are installed, starting with the model years shown in Table 1 
to this section:
    (1) Compression-ignition engines we regulate under 40 CFR part 1039. 
This includes stationary compression-ignition engines we regulate under 
the provisions of 40 CFR part 1039, as indicated under 40 CFR part 60, 
subpart IIII. See the evaporative emission standards specified in 40 CFR 
1048.105. These engines are considered to be Large SI engines for 
purposes of this part 1060.
    (2) Marine compression-ignition engines we regulate under 40 CFR 
part 1042. See the evaporative emission standards specified in 40 CFR 
1045.112. These engines are considered to be Marine SI engines for 
purposes of this part 1060.
    (3) Marine SI engines we regulate under 40 CFR part 1045. See the 
evaporative emission standards specified in 40 CFR 1045.112.
    (4) Large SI engines we regulate under 40 CFR part 1048. This 
includes stationary spark-ignition engines subject to standards under 40 
CFR parts 1048 or 1054 as indicated in 40 CFR part 60, subpart JJJJ. See 
the evaporative emission standards specified in 40 CFR 1048.105.
    (5) Recreational vehicles and engines we regulate under 40 CFR part 
1051 (such as snowmobiles and off-highway motorcycles). This includes 
highway motorcycles subject to standards under 40 CFR part 1051 as 
indicated in 40 CFR part 86, subpart E since these motorcycles are 
considered to be recreational vehicles for purposes of this part 1060. 
See the evaporative emission standards specified in 40 CFR 1051.110.
    (6) Small SI engines we regulate under 40 CFR part 1054. See the 
evaporative emission standards specified for handheld engines in 40 CFR 
1054.110 and for nonhandheld engines in 40 CFR 1054.112.
    (7) Portable nonroad fuel tanks are considered portable marine fuel 
tanks for purposes of this part. Portable nonroad fuel tanks and fuel 
lines associated with such fuel tanks must therefore meet evaporative 
emission standards specified in 40 CFR 1045.112, whether or not they are 
used with marine vessels.
    (b) The regulations in this part 1060 apply for new replacement 
components used with any of the engines or equipment specified in 
paragraph (a) of this section as described in Sec.  1060.601.
    (c) Fuel caps are subject to evaporative emission standards at the 
point of installation on a fuel tank. When a fuel cap is certified for 
use with Marine SI engines or Small SI engines under the optional 
standards of Sec.  1060.103, it becomes subject to all the requirements 
of this part as if these optional standards were mandatory.
    (d) This part does not apply to any diesel-fueled engine or any 
other engine that does not use a volatile liquid fuel. In addition, this 
part does not apply to any engines or equipment in the following 
categories even if they use a volatile liquid fuel:
    (1) Light-duty motor vehicles (see 40 CFR part 86).
    (2) Heavy-duty motor vehicles and heavy-duty motor vehicle engines 
(see 40 CFR part 86). This part also does not apply to fuel systems for 
nonroad engines where such fuel systems are subject to part 86 because 
they are part of a heavy-duty motor vehicle.
    (3) Aircraft engines (see 40 CFR part 87).
    (4) Locomotives (see 40 CFR part 1033).
    (e) This part 1060 does not apply for fuel lines made wholly of 
metal.

[[Page 7]]



                              Table 1 to Sec.   1060.1--Part 1060 Applicability \a\
----------------------------------------------------------------------------------------------------------------
      Equipment category or            Fuel line                                                 Running loss
           subcategory                permeation        Tank permeation    Diurnal emissions       emissions
----------------------------------------------------------------------------------------------------------------
Marine SI--portable marine fuel   January 1, 2009     January 1, 2011...  January 1, 2010...  Not applicable.
 tanks.                            \b\.
Marine SI--personal watercraft..  January 1, 2009...  Model year 2011...  Model year 2010...  Not applicable.
Marine SI--other vessels with     January 1, 2009     Model year 2012...  July 31, 2011.....  Not applicable.
 installed fuel tanks.             \b\.
Large SI........................  Model year 2007...  Not applicable....  Model year 2007     Model year 2007.
                                                                           (includes tank
                                                                           permeation).
Recreational vehicles...........  Model year 2008...  Model year 2008...  Not applicable....  Not applicable.
Small SI--handheld..............  Model year 2012     Model year 2010     Not applicable....  Not applicable.
                                   \c\.                \d\.
Small SI--Class I nonhandheld...  January 1, 2009...  Model year 2012...  Not applicable \e\  Model year 2012.
Small SI--Class II nonhandheld..  January 1, 2009...  Model year 2011...  Not applicable \e\  Model year 2011.
----------------------------------------------------------------------------------------------------------------
\a\ Implementation is based on the date of manufacture of the equipment. Where we do not identify a specific
  date, the emission standards start to apply at the beginning of the model year.
\b\ January 1, 2011 for primer bulbs. Standards phase in for under-cowl fuel lines on outboard engines, by
  length: 30% in 2010, 60% in 2011, 90% in 2012-2014, 100% in 2015.
\c\ 2013 for small-volume emission families that do not include cold-weather fuel lines.
\d\ 2011 for structurally integrated nylon fuel tanks and 2013 for all small-volume emission families.
\e\ Manufacturers may optionally meet diurnal standards as specified in Sec.   1060.105(e).


[73 FR 59298, Oct. 8, 2008, as amended at 86 FR 34527, June 29, 2021]



Sec.  1060.5  Do the requirements of this part apply to me?

    The requirements of this part are generally addressed to the 
manufacturers that are subject to this part's requirements as described 
in paragraph (a) of this section. The term ``you'' generally means the 
manufacturer or manufacturers that are subject to these requirements. 
Paragraphs (b) through (e) of this section describe which manufacturers 
may or must certify their products. (Note: Sec.  1060.601(f) allows the 
certification responsibility to be delegated in certain circumstances.)
    (a) Overall responsibilities. Manufacturers of the engines, 
equipment, and fuel-system components described in Sec.  1060.1 are 
subject to the standards and other requirements of this part 1060 except 
as otherwise noted. Multiple manufacturers may be subject to these 
standards and other requirements. For example, when a Small SI equipment 
manufacturer buys fuel line manufactured by another person and installs 
them in its equipment, both the equipment manufacturer and the fuel line 
manufacturer are subject to the standards and other requirements of this 
part. The following provisions apply in such cases:
    (1) Each person meeting the definition of manufacturer (see Sec.  
1060.801) for a product that is subject to the standards and other 
requirements of this part must comply with such requirements. However, 
if one person complies with a specific requirement for a given product, 
then all manufacturers are deemed to have complied with that specific 
requirement. For example, if a Small SI equipment manufacturer uses fuel 
lines manufactured and certified by another company, the equipment 
manufacturer is not required to obtain its own certificate with respect 
to the fuel line emission standards. Such an equipment manufacturer 
remains subject to the standards and other requirements of this part. 
However, where a provision in this part requires a specific manufacturer 
to comply with certain provisions, this paragraph (a) does not change or 
modify such a requirement. For example, this paragraph (a) does not 
allow you to rely on another company to certify instead of you if we 
specifically require you to certify.
    (2) The requirements of subparts C and D of this part apply to the 
manufacturer that obtains the certificate of conformity. Other 
manufacturers are required to comply with the requirements of subparts C 
and D of this part

[[Page 8]]

only when we send notification. In our notification, we will specify a 
reasonable period for complying with the requirements identified in the 
notice. See Sec.  1060.601 for the applicability of 40 CFR part 1068 to 
these other manufacturers.
    (3) Certificate holders are responsible for meeting all applicable 
requirements even if other manufacturers are also subject to those 
requirements.
    (b) Marine SI. Certify vessels, engines, and fuel-system components 
as follows:
    (1) Component manufacturers must certify their fuel lines and fuel 
tanks intended for installation with Marine SI engines and vessels under 
this part 1060, except as allowed by Sec.  1060.601(f). This includes 
permeation and diurnal emission standards.
    (2) Vessel manufacturers are subject to all the requirements of this 
part 1060 that apply to Marine SI engines and fuel systems. However, 
they must certify to the emission standards specified in Sec. Sec.  
1060.102 through 1060.105 only if one or more of the following 
conditions apply:
    (i) Vessel manufacturers must certify fuel system components they 
install in their vessels if the components are not certified to meet all 
applicable evaporative emission standards, including both permeation and 
diurnal standards. This would include vessel manufacturers that make 
their own fuel tanks. Vessel manufacturers would need to act as 
component manufacturers to certify under this part 1060.
    (ii) Vessel manufacturers must certify their vessels only if they 
intend to generate or use evaporative emission credits. Vessel 
manufacturers would certify under part 40 CFR part 1045 using the 
emission-credit provisions in subpart H of that part to demonstrate 
compliance with the emission standard.
    (3) Engine manufacturers must meet all the requirements of this part 
1060 that apply to vessel manufacturers for all fuel-system components 
they install on their engines. For example, engine manufacturers that 
install under-cowl fuel lines and fuel tanks must comply with the 
requirements specified for vessel manufacturers with respect to those 
components.
    (c) Large SI. Certify engines, equipment, and fuel-system components 
as follows:
    (1) Engine manufacturers must certify their engines under 40 CFR 
part 1048.
    (2) Equipment manufacturers and component manufacturers may certify 
fuel lines and fuel tanks intended for use with Large SI engines under 
this part 1060.
    (d) Recreational vehicles. Certify vehicles, engines and fuel-system 
components as follows:
    (1) Vehicle manufacturers must certify their vehicles under 40 CFR 
part 1051.
    (2) Engine manufacturers must meet all the requirements of 40 CFR 
part 1051 that apply to vehicle manufacturers for all fuel-system 
components they install on their engines. For example, engine 
manufacturers that install fuel-line segments on the engines they ship 
to vehicle manufacturers must comply with the requirements specified for 
equipment manufacturers with respect to those components.
    (3) Component manufacturers may certify fuel lines and fuel tanks 
intended for recreational vehicles under this part 1060.
    (e) Small SI. Certify engines, equipment, and fuel-system components 
as follows:
    (1) Component manufacturers must certify their fuel lines and fuel 
tanks intended for Small SI engines and equipment under this part 1060, 
except as allowed by Sec.  1060.601(f).
    (2) Equipment manufacturers must certify fuel system components they 
install in their equipment if the components are not certified to meet 
applicable evaporative emission standards. Equipment manufacturers would 
need to act as component manufacturers to certify fuel-system components 
under this part 1060.
    (3) Engine manufacturers must meet all the requirements of this part 
1060 that apply to equipment manufacturers for all fuel-system 
components they install on their engines. Engine manufacturers that 
produce Small SI engines with complete fuel systems are considered the 
equipment manufacturers for those engines under this part 1060.

[[Page 9]]

    (4) Equipment manufacturers must certify their equipment and are 
subject to all the requirements of this part 1060; however, this does 
not apply for equipment using portable nonroad fuel tanks.
    (f) Summary of certification responsibilities. Tables 1 through 3 of 
this section summarize the certification responsibilities for different 
kinds of manufacturers as described in paragraphs (b) through (e) of 
this section. The term ``No'' as used in the tables means that a 
manufacturer is not required to obtain a certificate of conformity under 
paragraphs (b) through (e) of this section. In situations where multiple 
manufacturers are subject to the standards and other requirements of 
this part, such a manufacturer must nevertheless certify if the 
manufacturer who is required to certify under paragraphs (b) through (e) 
of this section fails to obtain a certificate of conformity.

       Table 1 to Sec.   1060.5--Summary of Engine Manufacturer Evaporative Certification Responsibilities
----------------------------------------------------------------------------------------------------------------
                                             Is the engine manufacturer
                                              required to certify for       Code of Federal Regulations Cite for
             Equipment type               evaporative emission standards?              Certification
                                                        \a\
----------------------------------------------------------------------------------------------------------------
Marine SI...............................  No.............................
Large SI................................  Yes............................  40 CFR part 1048.
Recreational vehicles...................  No.............................
Small SI................................  No, unless engines are sold      40 CFR part 1060.
                                           with complete fuel systems.
----------------------------------------------------------------------------------------------------------------
\a\ Fuel lines and fuel tanks that are attached to or sold with engines must be covered by a certificate of
  conformity.


     Table 2 to Sec.   1060.5--Summary of Equipment Manufacturer Evaporative Certification Responsibilities
----------------------------------------------------------------------------------------------------------------
                                           Is the equipment manufacturer
             Equipment type                   required to certify for       Code of Federal Regulations Cite for
                                          evaporative emission standards?              Certification
----------------------------------------------------------------------------------------------------------------
Marine SI...............................  Yes, but only if vessel          40 CFR part 1060.\a\
                                           manufacturers install
                                           uncertified fuel lines or fuel
                                           tanks, or they intend to
                                           generate or use evaporative
                                           emission credits.
Large SI................................  Allowed but not required.......  40 CFR part 1060.
Recreational vehicles...................  Yes, even if vehicle             40 CFR part 1051.
                                           manufacturers install
                                           certified components.
Small SI................................  Yes, unless the equipment uses   40 CFR part 1060.\a\
                                           portable nonroad fuel tanks.
----------------------------------------------------------------------------------------------------------------
\a\ See the exhaust standard-setting part for provisions related to generating or using evaporative emission
  credits.


           Table 3 of Sec.   1060.5--Summary of Component Manufacturer Certification Responsibilities
----------------------------------------------------------------------------------------------------------------
                                           Is the component manufacturer
             Equipment type                required to certify fuel lines   Code of Federal Regulations Cite for
                                                  and fuel tanks?                      Certification
----------------------------------------------------------------------------------------------------------------
Marine SI...............................  Yes, including portable marine   40 CFR part 1060.
                                           fuel tanks and associated fuel
                                           lines \a\.
Large SI................................  Allowed but not required.......  40 CFR part 1060.
Recreational vehicles...................  Allowed but not required.......  40 CFR part 1060.
Small SI................................  Yes \a\........................  40 CFR part 1060.
----------------------------------------------------------------------------------------------------------------
\a\ See Sec.   1060.601 for an allowance to make contractual arrangements with engine or equipment manufacturers
  instead of certifying.


[73 FR 59298, Oct. 8, 2008, as amended at 80 FR 9115, Feb. 19, 2015; 86 
FR 34528, June 29, 2021]



Sec.  1060.10  How is this part organized?

    This part 1060 is divided into the following subparts:
    (a) Subpart A of this part defines the applicability of part 1060 
and gives an overview of regulatory requirements.
    (b) Subpart B of this part describes the emission standards and 
other requirements that must be met to certify equipment or components 
under this part. Note that Sec.  1060.110 discusses certain interim 
requirements and compliance provisions that apply only for a limited 
time.
    (c) Subpart C of this part describes how to apply for a certificate 
of conformity.
    (d) Subpart D of this part describes the requirements related to 
verifying

[[Page 10]]

that products are being produced as described in an approved application 
for certification.
    (e) Subpart E of this part describes the requirements related to 
verifying that products are meeting the standards in use.
    (f) Subpart F of this part describes how to measure evaporative 
emissions.
    (g) Subpart G of this part and 40 CFR part 1068 describe 
requirements, prohibitions, and other provisions that apply to 
manufacturers, owners, operators, and all others.
    (h) Subpart H of this part describes how to certify your equipment 
or components for inclusion in an emission averaging program allowed by 
an exhaust standard-setting part.
    (i) Subpart I of this part contains definitions and other reference 
information.



Sec.  1060.15  Do any other CFR parts apply to me?

    (a) There is a separate part of the CFR that includes exhaust 
emission requirements for each particular application, as described in 
Sec.  1060.1(a). We refer to these as the exhaust standard-setting 
parts. In cases where an exhaust standard-setting part includes 
evaporative requirements, apply this part 1060 as specified in the 
exhaust standard-setting part, as follows:
    (1) The requirements in the exhaust standard-setting part may differ 
from the requirements in this part. In cases where it is not possible to 
comply with both the exhaust standard-setting part and this part, you 
must comply with the requirements in the exhaust standard-setting part. 
The exhaust standard-setting part may also allow you to deviate from the 
procedures of this part for other reasons.
    (2) The exhaust standard-setting parts may reference some sections 
of this part 1060 or may allow or require certification under this part 
1060. See the exhaust standard-setting parts to determine what 
provisions of this part 1060 apply for these equipment types.
    (b) The requirements and prohibitions of part 1068 of this chapter 
apply to everyone, including anyone who manufactures, imports, owns, 
operates, or services any of the fuel systems subject to this part 1060. 
Part 1068 of this chapter describes general provisions, including the 
following areas:
    (1) Prohibited acts and penalties for engine manufacturers, 
equipment manufacturers, and others.
    (2) Exclusions and exemptions for certain products.
    (3) Importing products.
    (4) Defect reporting and recall.
    (5) Procedures for hearings.
    (c) Other parts of this chapter apply if referenced in this part.



Sec.  1060.30  Submission of information.

    Unless we specify otherwise, send all reports and requests for 
approval to the Designated Compliance Officer (see Sec.  1060.801). See 
Sec.  1060.825 for additional reporting and recordkeeping provisions.

[86 FR 34528, June 29, 2021]



          Subpart B_Emission Standards and Related Requirements



Sec.  1060.101  What evaporative emission requirements apply under this part?

    Products subject to this part must meet emission standards and 
related requirements as follows:
    (a) Section 1060.102 describes permeation emission control 
requirements for fuel lines.
    (b) Section 1060.103 describes permeation emission control 
requirements for fuel tanks.
    (c) Section 1060.104 describes running loss emission control 
requirements for fuel systems.
    (d) Section 1060.105 describes diurnal emission control requirements 
for fuel tanks.
    (e) The following general requirements apply for components and 
equipment subject to the emission standards in Sec. Sec.  1060.102 
through 1060.105:
    (1) Adjustable parameters. Components or equipment with adjustable 
parameters must meet all the requirements of this part for any 
adjustment in the practically adjustable range. See 40 CFR 1068.50.
    (2) Prohibited controls. The following controls are prohibited:
    (i) For anyone to design, manufacture, or install emission control 
systems so they cause or contribute to an

[[Page 11]]

unreasonable risk to public health, welfare, or safety while operating.
    (ii) For anyone to design, manufacture, or install emission control 
systems with features that disable, deactivate, or bypass the emission 
controls, either actively or passively. For example, you may not include 
a manual vent that the operator can open to bypass emission controls. 
You may ask us to allow such features if needed for safety reasons or if 
the features are fully functional during emission tests described in 
subpart F of this part.
    (3) Emission credits. Equipment manufacturers are allowed to comply 
with the emission standards in this part using evaporative emission 
credits only if the exhaust standard-setting part explicitly allows it 
for evaporative emissions. See the exhaust standard-setting part and 
subpart H of this part for information about complying with evaporative 
emission credits. For equipment manufacturers to generate or use 
evaporative emission credits, components must be certified to a family 
emission limit, which serves as the standard for those components.
    (f) This paragraph (f) specifies requirements that apply to 
equipment manufacturers subject to requirements under this part, whether 
or not they are subject to and certify to any of the emission standards 
in Sec. Sec.  1060.102 through 1060.105. Equipment manufacturers meeting 
these requirements will be deemed to be certified as in conformity with 
the requirements of this paragraph (f) without submitting an application 
for certification, as follows:
    (1) Fuel caps, vents, and carbon canisters. You are responsible for 
ensuring that proper caps and vents are installed on each new piece of 
equipment that is subject to emission standards under this part. The 
following particular requirements apply to equipment that is subject to 
running loss or diurnal emission standards, including portable marine 
fuel tanks:
    (i) All equipment must have a tethered fuel cap. Fuel caps must also 
include a visual, audible, or other physical indication that they have 
been properly sealed.
    (ii) You may not add vents unless they are specified in or allowed 
by the applicable certificates of conformity.
    (iii) If the emission controls rely on carbon canisters, they must 
be installed in a way that prevents exposing the carbon to water or 
liquid fuel.
    (2) Fuel-line fittings. The following requirements apply for fuel-
line fittings that will be used with fuel lines that must meet 
permeation emission standards:
    (i) Use good engineering judgment to ensure that all fuel-line 
fittings will remain securely connected to prevent fuel leakage 
throughout the useful life of the equipment.
    (ii) Fuel lines that are intended to be detachable (such as those 
for portable marine fuel tanks) must be self-sealing when detached from 
the fuel tank or engine.
    (3) Refueling. For any equipment using fuel tanks that are subject 
to diurnal or permeation emission standards under this part, you must 
design and build your equipment such that operators can reasonably be 
expected to fill the fuel tank without spitback or spillage during the 
refueling event. The following examples illustrate designs that meet 
this requirement:
    (i) Equipment that is commonly refueled using a portable gasoline 
container should have a fuel tank inlet that is larger than a typical 
dispensing spout. The fuel tank inlet should be located so the operator 
can place the nozzle directly in the fuel tank inlet and see the fuel 
level in the tank while pouring the fuel from an appropriately sized 
refueling container (either through the tank wall or the fuel tank 
inlet). We will deem you to comply with the requirements of this 
paragraph (f)(3)(i) if you design your equipment to meet applicable 
industry standards related to fuel tank inlets.
    (ii) Marine SI vessels with a filler neck extending to the side of 
the boat should be designed for automatic fuel shutoff. Alternatively, 
the filler neck should be designed such that the orientation of the 
filler neck allows dispensed fuel that collects in the filler neck to 
flow back into the fuel tank. A filler neck that ends with a horizontal 
or nearly horizontal segment at the

[[Page 12]]

opening where fuel is dispensed would not be an acceptable design.
    (g) Components and equipment must meet the standards specified in 
this part throughout the applicable useful life. Where we do not specify 
procedures for demonstrating the durability of emission controls, use 
good engineering judgment to ensure that your products will meet the 
standards throughout the useful life. The useful life is one of the 
following values:
    (1) The useful life in years specified for the components or 
equipment in the exhaust standard-setting part.
    (2) The useful life in years specified for the engine in the exhaust 
standard-setting part if the exhaust standards are specified for the 
engine rather than the equipment and there is no useful life given for 
components or equipment.
    (3) Five years if no useful life is specified in years for the 
components, equipment, or engines in the exhaust standard-setting part.

[73 FR 59298, Oct. 8, 2008, as amended at 88 FR 4669, Jan. 24, 2023]



Sec.  1060.102  What permeation emission control requirements 
apply for fuel lines?

    (a) Nonmetal fuel lines must meet permeation requirements as 
follows:
    (1) Marine SI fuel lines, including fuel lines associated with 
outboard engines or portable marine fuel tanks, must meet the permeation 
requirements in this section.
    (2) Large SI fuel lines must meet the permeation requirements 
specified in 40 CFR 1048.105.
    (3) Fuel lines for recreational vehicles must meet the permeation 
requirements specified in 40 CFR 1051.110 or in this section.
    (4) Small SI fuel lines must meet the permeation requirements in 
this section, unless they are installed in equipment certified to meet 
diurnal emission standards under Sec.  1060.105(e).
    (b) Different categories of nonroad equipment are subject to 
different requirements with respect to fuel line permeation. Fuel lines 
are classified based on measured emissions over the test procedure 
specified for the class.
    (c) The regulations in 40 CFR part 1048 require that fuel lines used 
with Large SI engines must meet the standards for EPA Low-Emission Fuel 
Lines. The regulations in 40 CFR part 1054 require that fuel lines used 
with handheld Small SI engines installed in cold-weather equipment must 
meet the standards for EPA Cold-Weather Fuel Lines. Unless specified 
otherwise in this subchapter U, fuel lines used with all other engines 
and equipment subject to the provisions of this part 1060, including 
fuel lines associated with outboard engines or portable marine fuel 
tanks, must meet the standards for EPA Nonroad Fuel Lines.
    (d) The following standards apply for each fuel line classification:
    (1) EPA Low-Emission Fuel Lines must have permeation emissions at or 
below 10 g/m\2\/day when measured according to the test procedure 
described in Sec.  1060.510. Fuel lines that comply with this emission 
standard are deemed to comply with all the emission standards specified 
in this section.
    (2) EPA Nonroad Fuel Lines must have permeation emissions at or 
below 15 g/m\2\/day when measured according to the test procedure 
described in Sec.  1060.515.
    (3) EPA Cold-Weather Fuel Lines must meet the following permeation 
emission standards when measured according to the test procedure 
described in Sec.  1060.515:

  Table 1 to Sec.   1060.102--Permeation Standards for EPA Cold-Weather
                               Fuel Lines
------------------------------------------------------------------------
                                                           Standard (g/
                       Model year                            m\2\/day)
------------------------------------------------------------------------
2012....................................................             290
2013....................................................             275
2014....................................................             260
2015....................................................             245
2016 and later..........................................             225
------------------------------------------------------------------------

    (e) You may certify fuel lines as follow:
    (1) You may certify straight-run fuel lines as sections of any 
length.
    (2) You may certify molded fuel lines in any configuration 
representing your actual production, subject to the provisions for 
selecting a worst-case configuration in Sec.  1060.235(b).
    (3) You may certify fuel line assemblies as aggregated systems that 
include multiple sections of fuel line with connectors and fittings. For 
example, you may certify fuel lines for

[[Page 13]]

portable marine fuel tanks as assemblies of fuel hose, primer bulbs, and 
self-sealing end connections. The length of such an assembly must not be 
longer than a typical in-use installation and must always be less than 
2.5 meters long. You may also certify primer bulbs separately. The 
standard applies with respect to the total permeation emissions divided 
by the wetted internal surface area of the assembly. Where it is not 
practical to determine the actual internal surface area of the assembly, 
you may assume that the internal surface area per unit length of the 
assembly is equal to the ratio of internal surface area per unit length 
of the hose section of the assembly.

[73 FR 59298, Oct. 8, 2008, as amended at 74 FR 8426, Feb. 24, 2009]



Sec.  1060.103  What permeation emission control requirements apply for fuel tanks?

    (a) Fuel tanks must meet permeation requirements as follows:
    (1) Marine SI fuel tanks, including engine-mounted fuel tanks and 
portable marine fuel tanks, must meet the permeation requirements in 
this section.
    (2) Large SI fuel tanks must meet diurnal emission standards as 
specified in Sec.  1060.105, which includes measurement of permeation 
emissions. No separate permeation standard applies.
    (3) Fuel tanks for recreational vehicles must meet the permeation 
requirements specified in 40 CFR 1051.110 or in this section.
    (4) Small SI fuel tanks must meet the permeation requirements in 
this section unless they are installed in equipment certified to meet 
diurnal emission standards under Sec.  1060.105(e).
    (b) Permeation emissions from fuel tanks may not exceed 1.5 g/m\2\/
day when measured at a nominal temperature of 28 [deg]C with the test 
procedures for tank permeation in Sec.  1060.520. You may also choose to 
meet a standard of 2.5 g/m\2\/day if you perform testing at a nominal 
temperature of 40 [deg]C under Sec.  1060.520(d).
    (c) The exhaust standard-setting part may allow for certification of 
fuel tanks to a family emission limit for calculating evaporative 
emission credits as described in subpart H of this part instead of 
meeting the emission standards in this section.
    (d) For purposes of this part, fuel tanks do not include fuel lines 
that are subject to Sec.  1060.102, petcocks designed for draining fuel, 
grommets used with fuel lines, or grommets used with other hose or 
tubing excluded from the definition of ``fuel line.'' Fuel tanks include 
other fittings (such as fuel caps, gaskets, and O-rings) that are 
directly mounted to the fuel tank.
    (e) Fuel caps may be certified separately relative to the permeation 
emission standard in paragraph (b) of this section using the test 
procedures specified in Sec.  1060.521. Fuel caps certified alone do not 
need to meet the emission standard. Rather, fuel caps would be certified 
with a Family Emission Limit, which is used for demonstrating that fuel 
tanks meet the emission standard as described in Sec.  1060.520(b)(5). 
For the purposes of this paragraph (e), gaskets or O-rings that are 
produced as part of an assembly with the fuel cap are considered part of 
the fuel cap.
    (f) Metal fuel tanks that meet the permeation criteria in Sec.  
1060.240(d)(2) or use certified nonmetal fuel caps will be deemed to be 
certified as in conformity with the requirements of this section without 
submitting an application for certification.

[73 FR 59298, Oct. 8, 2008, as amended at 74 FR 8427, Feb. 24, 2009; 75 
FR 23026, Apr. 30, 2010]



Sec.  1060.104  What running loss emission control requirements apply?

    (a) Engines and equipment must meet running loss requirements as 
follows:
    (1) Marine SI engines and vessels are not subject to running loss 
emission standards.
    (2) Large SI engines and equipment must prevent fuel boiling during 
operation as specified in 40 CFR 1048.105.
    (3) Recreational vehicles are not subject to running loss emission 
standards.
    (4) Nonhandheld Small SI engines and equipment that are not used in 
wintertime equipment must meet running loss requirements described in 
this section. Handheld Small SI engines and equipment are not subject to 
running loss emission standards.

[[Page 14]]

    (b) You must demonstrate control of running loss emissions in one of 
the following ways if your engines or equipment are subject to the 
requirements of this section:
    (1) Route running loss emissions into the engine intake system so 
fuel vapors vented from the tank during engine operation are combusted 
in the engine. This may involve routing vapors through a carbon 
canister. If another company has certified the engine with respect to 
exhaust emissions, state in your application for certification that you 
have followed the engine manufacturer's installation instructions.
    (2) Use a fuel tank that remains sealed under normal operating 
conditions. This may involve a bladder or other means to prevent 
pressurized fuel tanks.
    (3) Get an approved executive order or other written approval from 
the California Air Resources Board showing that your system meets 
applicable running loss standards in California.
    (c) If you are subject to both running loss and diurnal emission 
standards, use good engineering judgment to ensure that the emission 
controls are compatible.

[73 FR 59298, Oct. 8, 2008, as amended at 86 FR 34528, June 29, 2021]



Sec.  1060.105  What diurnal requirements apply for equipment?

    (a) Fuel tanks must meet diurnal emission requirements as follows:
    (1) Marine SI fuel tanks, including engine-mounted fuel tanks and 
portable marine fuel tanks, must meet the requirements related to 
diurnal emissions specified in this section.
    (2) Large SI fuel tanks must meet the requirements related to 
diurnal emissions specified in 40 CFR 1048.105.
    (3) Recreational vehicles are not subject to diurnal emission 
standards.
    (4) Small SI fuel tanks are not subject to diurnal emission 
standards, except as specified in paragraph (e) of this section.
    (b) Diurnal emissions from Marine SI fuel tanks may not exceed 0.40 
g/gal/day when measured using the test procedures specified in Sec.  
1060.525 for general fuel temperatures. An alternative standard of 0.16 
g/gal/day applies for fuel tanks installed in nontrailerable boats when 
measured using the corresponding fuel temperature profile in Sec.  
1060.525. Portable marine fuel tanks are not subject to the requirements 
of this paragraph (b), but must instead comply with the requirements of 
paragraphs (c) and (d) of this section.
    (c) Portable marine fuel tanks and associated fuel-system components 
must meet the following requirements:
    (1) They must be self-sealing when detached from the engines. The 
tanks may not vent to the atmosphere when attached to an engine, except 
as allowed under paragraph (c)(2) of this section. An integrated or 
external manually activated device may be included in the fuel tank 
design to temporarily relieve pressure before refueling or connecting 
the fuel tank to the engine. However, the default setting for such a 
vent must be consistent with the requirement in paragraph (c)(2) of this 
section.
    (2) They must remain sealed up to a positive pressure of 24.5 kPa 
(3.5 psig); however, they may contain air inlets that open when there is 
a vacuum pressure inside the tank. Such fuel tanks may not contain air 
outlets that vent to the atmosphere at pressures below 34.5 kPa (5.0 
psig).
    (d) Detachable fuel lines that are intended for use with portable 
marine fuel tanks must have connection points that are self-sealing when 
not attached to the engine or fuel tank.
    (e) Manufacturers of nonhandheld Small SI equipment may optionally 
meet the diurnal emission standards adopted by the California Air 
Resources Board. To meet the requirement in this paragraph (e), 
equipment must be certified to the performance standards specified in 
Title 13 California Code of Regulations (CCR) 2754(a) based on the 
applicable requirements specified in CP-902 and TP-902, including the 
requirements related to fuel caps in Title 13 CCR 2756. Equipment 
certified under this paragraph (e) does not need to use fuel lines or 
fuel tanks that have been certified separately. Equipment certified 
under this paragraph (e) are subject to all the referenced requirements 
in this paragraph (e) as if these specifications were mandatory.

[[Page 15]]

    (f) The following general provisions apply for controlling diurnal 
emissions:
    (1) If you are subject to both running loss and diurnal emission 
standards, use good engineering judgment to ensure that the emission 
controls are compatible.
    (2) You may not use diurnal emission controls that increase the 
occurrence of fuel spitback or spillage during in-use refueling. Also, 
if you use a carbon canister, you must incorporate design features that 
prevent liquid gasoline from reaching the canister during refueling or 
as a result of fuel sloshing or fuel expansion.
    (3) You must meet the following provisions from ABYC H-25, July 2010 
(incorporated by reference in Sec.  1060.810) with respect to portable 
marine fuel tanks:
    (i) Provide information related to the pressure relief method 
(25.8.2.1 and 25.8.2.1.1).
    (ii) Perform system testing (25.10 through 25.10.5).

[73 FR 59298, Oct. 8, 2008, as amended at 74 FR 8427, Feb. 24, 2009; 75 
FR 56482, Sept. 16, 2010; 86 FR 34528, June 29, 2021]



Sec.  1060.120  What emission-related warranty requirements apply?

    (a) General requirements. The certifying manufacturer must warrant 
to the ultimate purchaser and each subsequent purchaser that the new 
nonroad equipment, including its evaporative emission control system, 
meets two conditions:
    (1) It is designed, built, and equipped so it conforms at the time 
of sale to the ultimate purchaser with the requirements of this part.
    (2) It is free from defects in materials and workmanship that may 
keep it from meeting these requirements.
    (b) Warranty period. Your emission-related warranty must be valid 
for at least two years from the date the equipment is sold to the 
ultimate purchaser.
    (c) Components covered. The emission-related warranty covers all 
components whose failure would increase the evaporative emissions, 
including those listed in 40 CFR part 1068, appendix I, and those from 
any other system you develop to control emissions. Your emission-related 
warranty does not need to cover components whose failure would not 
increase evaporative emissions.
    (d) Relationships between manufacturers. (1) The emission-related 
warranty required for equipment manufacturers that certify equipment 
must cover all specified components even if another company produces the 
component.
    (2) Where an equipment manufacturer fulfills a warranty obligation 
for a given component, the component manufacturer is deemed to have also 
met that obligation.

[73 FR 59298, Oct. 8, 2008, as amended at 86 FR 34528, June 29, 2021]



Sec.  1060.125  What maintenance instructions must I give to buyers?

    Give ultimate purchasers written instructions for properly 
maintaining and using the emission control system. You may not specify 
any maintenance more frequently than once per year. For example, if you 
produce cold-weather equipment that requires replacement of fuel cap 
gaskets or O-rings, provide clear instructions to the ultimate 
purchaser, including the required replacement interval.



Sec.  1060.130  What installation instructions must I give 
to equipment manufacturers?

    (a) If you sell a certified fuel-system component for someone else 
to install in equipment, give the installer instructions for installing 
it consistent with the requirements of this part.
    (b) Make sure the instructions have the following information:
    (1) Include the heading: ``Emission-related installation 
instructions''.
    (2) State: ``Failing to follow these instructions when installing 
[IDENTIFY COMPONENT(S)] in a piece of nonroad equipment violates federal 
law (40 CFR 1068.105(b)), subject to fines or other penalties as 
described in the Clean Air Act.''
    (3) Describe how your certification is limited for any type of 
application. For example:
    (i) For fuel tanks sold without fuel caps, you must specify the 
requirements for the fuel cap, such as the allowable materials, thread 
pattern, how

[[Page 16]]

it must seal, etc. You must also include instructions to tether the fuel 
cap as described in Sec.  1060.101(f)(1) if you do not sell your fuel 
tanks with tethered fuel caps. The following instructions apply for 
specifying a certain level of emission control for fuel caps that will 
be installed on your fuel tanks:
    (A) If your testing involves a default emission value for fuel cap 
permeation as specified in Sec.  1060.520(b)(5)(ii)(C), specify in your 
installation instructions that installed fuel caps must either be 
certified with a Family Emission Limit at or below 30 g/m2/day, or have 
gaskets made of certain materials meeting the definition of ``low-
permeability material'' in Sec.  1060.801.
    (B) If you certify your fuel tanks based on a fuel cap certified 
with a Family Emission Limit above 30 g/m2/day, specify in your 
installation instructions that installed fuel caps must either be 
certified with a Family Emission Limit at or below the level you used 
for certifying your fuel tanks, or have gaskets made of certain 
materials meeting the definition of ``low-permeability material'' in 
Sec.  1060.801.
    (ii) If your fuel lines do not meet permeation standards specified 
in Sec.  1060.102 for EPA Low-Emission Fuel Lines, tell equipment 
manufacturers not to install the fuel lines with Large SI engines that 
operate on gasoline or another volatile liquid fuel.
    (4) Describe instructions for installing components so they will 
operate according to design specifications in your application for 
certification. Specify sufficient detail to ensure that the equipment 
will meet the applicable standards when your component is installed.
    (5) If you certify a component with a family emission limit above 
the emission standard, be sure to indicate that the equipment 
manufacturer must have a source of credits to offset the higher 
emissions. Also indicate the applications for which the regulations 
allow for compliance using evaporative emission credits.
    (6) Instruct the equipment manufacturers that they must comply with 
the requirements of Sec.  1060.202.
    (c) You do not need installation instructions for components you 
install in your own equipment.
    (d) Provide instructions in writing or in an equivalent format. For 
example, you may post instructions on a publicly available Web site for 
downloading or printing, provided you keep a copy of these instructions 
in your records. If you do not provide the instructions in writing, 
explain in your application for certification how you will ensure that 
each installer is informed of the installation requirements.

[73 FR 59298, Oct. 8, 2008, as amended at 86 FR 34528, June 29, 2021]



Sec.  1060.135  How must I label and identify the engines and 
equipment I produce?

    The labeling requirements of this section apply for all equipment 
manufacturers that are required to certify their equipment or use 
certified fuel-system components. Note that engine manufacturers are 
also considered equipment manufacturers if they install a complete fuel 
system on an engine. See Sec.  1060.137 for the labeling requirements 
that apply separately for fuel lines, fuel tanks, and other fuel-system 
components.
    (a) At the time of manufacture, you must affix a permanent and 
legible label identifying each engine or piece of equipment. The label 
must be--
    (1) Attached in one piece so it is not removable without being 
destroyed or defaced.
    (2) Secured to a part of the engine or equipment needed for normal 
operation and not normally requiring replacement.
    (3) Durable and readable for the equipment's entire life.
    (4) Written in English.
    (5) Readily visible in the final installation. It may be under a 
hinged door or other readily opened cover. It may not be hidden by any 
cover attached with screws or any similar designs. Labels on marine 
vessels (except personal watercraft) must be visible from the helm.
    (b) If you hold a certificate under this part for your engine or 
equipment, the engine or equipment label specified in paragraph (a) of 
this section must--

[[Page 17]]

    (1) Include the heading ``EMISSION CONTROL INFORMATION''.
    (2) Include your corporate name and trademark. You may identify 
another company and use its trademark instead of yours if you comply 
with the branding provisions of 40 CFR 1068.45.
    (3) State the date of manufacture [MONTH and YEAR] of the equipment; 
however, you may omit this from the label if you stamp, engrave, or 
otherwise permanently identify it elsewhere on the equipment, in which 
case you must also describe in your application for certification where 
you will identify the date on the equipment.
    (4) State: ``THIS [equipment, vehicle, boat, etc.] MEETS U.S. EPA 
EVAP STANDARDS.''
    (5) Identify the certified fuel-system components installed on the 
equipment as described in this paragraph (b)(5). Establish a component 
code for each certified fuel-system component, including those certified 
by other companies. You may use part numbers, certification numbers, or 
any other unique code that you or the certifying component manufacturer 
establish. This identifying information must correspond to printing or 
other labeling on each certified fuel-system component, whether you or 
the component manufacturer certifies the individual component. You may 
identify multiple part numbers if your equipment design might include an 
option to use more than one component design (such as from multiple 
component manufacturers). Use one of the following methods to include 
information on the label that identifies certified fuel-system 
components:
    (i) Use the component codes to identify each certified fuel-system 
component on the label specified in this paragraph (b).
    (ii) Identify the emission family on the label using EPA's 
standardized designation or an abbreviated equipment code that you 
establish in your application for certification. Equipment manufacturers 
that also certify their engines with respect to exhaust emissions may 
use the same emission family name for both exhaust and evaporative 
emissions. If you use the provisions of this paragraph (b)(5)(ii), you 
must identify all the certified fuel-system components and the 
associated component codes in your application for certification. In 
this case the label specified in this paragraph (b) may omit the 
information related to specific fuel-system components.
    (c) If you produce equipment without certifying with respect to 
evaporative emissions, the equipment label specified in paragraph (a) of 
this section must--
    (1) State: ``MEETS U.S. EPA EVAP STANDARDS USING CERTIFIED 
COMPONENTS.''
    (2) Include your corporate name.
    (d) You may add information to the emission control information 
label as follows:
    (1) You may identify other emission standards that the engine meets 
or does not meet (such as California standards). You may include this 
information by adding it to the statement we specify or by including a 
separate statement.
    (2) You may add other information to ensure that the engine will be 
properly maintained and used.
    (3) You may add appropriate features to prevent counterfeit labels. 
For example, you may include the engine's unique identification number 
on the label.
    (e) Anyone subject to the labeling requirements in this part 1060 
may ask us to approve modified labeling requirements if it is necessary 
or appropriate. We will approve the request if the alternate label is 
consistent with the requirements of this part.

[73 FR 59298, Oct. 8, 2008, as amended at 75 FR 23026, Apr. 30, 2010; 86 
FR 34529, June 29, 2021]



Sec.  1060.137  How must I label and identify the fuel-system
components I produce?

    The requirements of this section apply for manufacturers of fuel-
system components subject to emission standards under this part 1060. 
However, these requirements do not apply if you produce fuel-system 
components that will be covered by a certificate of conformity from 
another company under Sec.  1060.601(f). These requirements also do not 
apply for components you certify if you also certify the equipment in 
which the component is installed and

[[Page 18]]

meet the labeling requirements in Sec.  1060.135.
    (a) Label the components identified in this paragraph (a), unless 
the components are too small to be properly labeled. Unless we approve 
otherwise, we consider parts large enough to be properly labeled if they 
have space for 12 characters in six-point font (approximately 2 mm x 12 
mm). For these small parts, you may omit the label as long as you 
identify those part numbers in your maintenance and installation 
instructions.
    (1) All fuel tanks, except for metal fuel tanks that are deemed 
certified under Sec.  1060.103(f).
    (2) Fuel lines. This includes primer bulbs unless they are excluded 
from the definition of ``fuel line'' under the standard-setting part. 
Label primer bulbs separately.
    (3) Carbon canisters.
    (4) Fuel caps, as described in this paragraph (a)(4). Fuel caps must 
be labeled if they are separately certified under Sec.  1060.103. If the 
equipment has a diurnal control system that requires the fuel tank to 
hold pressure, identify the part number on the fuel cap.
    (5) Replaceable pressure-relief assemblies. This does not apply if 
the component is integral to the fuel tank or fuel cap.
    (6) Other components we determine to be critical to the proper 
functioning of evaporative emission controls.
    (b) Label your certified fuel-system components at the time of 
manufacture. The label must be--
    (1) Attached so it is not removable without being destroyed or 
defaced. This may involve printing directly on the product. For molded 
products, you may use the mold to apply the label.
    (2) Durable and readable for the equipment's entire life.
    (3) Written in English.
    (c) Except as specified in paragraph (d) of this section, you must 
create the label specified in paragraph (b) of this section as follows:
    (1) Include your corporate name. You may identify another company 
instead of yours if you comply with the provisions of 40 CFR 1068.45.
    (2) Include EPA's standardized designation for the emission family.
    (3) State: ``EPA COMPLIANT''.
    (4) Fuel tank labels must identify the FEL, if applicable.
    (5) Fuel line labels must identify the applicable permeation level. 
This may involve any of the following approaches:
    (i) Identify the applicable numerical emission standard (such as 15 
g/m \2\/day).
    (ii) Identify the applicable emission standards using EPA 
classifications (such as EPA Nonroad Fuel Lines).
    (iii) Identify the applicable industry standard specification (such 
as SAE J30 R12).
    (6) Fuel line labels must be continuous, with no more than 12 inches 
before repeating. We will consider labels to be continuous if the space 
between repeating segments is no longer than that of the repeated 
information. You may add a continuous stripe or other pattern to help 
identify the particular type or grade of your products.
    (d) You may create an abbreviated label for your components. Such a 
label may rely on codes to identify the component. The code must at a 
minimum identify the certification status, your corporate name, and the 
emission family. For example, XYZ Manufacturing may label its fuel lines 
as ``EPA-XYZ-A15'' to designate that their ``A15'' family was certified 
to meet EPA's 15 g/m \2\/day standard. If you do this, you must describe 
the abbreviated label in your application for certification and identify 
all the associated information specified in paragraph (c) of this 
section.
    (e) You may ask us to approve modified labeling requirements in this 
section as described in Sec.  1060.135(e).

[73 FR 59298, Oct. 8, 2008, as amended at 75 FR 23026, Apr. 30, 2010; 86 
FR 34529, June 29, 2021]



                 Subpart C_Certifying Emission Families



Sec.  1060.201  What are the general requirements for obtaining
a certificate of conformity?

    Manufacturers of engines, equipment, or fuel-system components may 
need to certify their products with respect to evaporative emission 
standards as described in Sec. Sec.  1060.1 and 1060.601. See Sec.  
1060.202 for requirements related to

[[Page 19]]

certifying with respect to the requirements specified in Sec.  
1060.101(f). The following general requirements apply for obtaining a 
certificate of conformity:
    (a) You must send us a separate application for a certificate of 
conformity for each emission family. A certificate of conformity for 
equipment is valid starting with the indicated effective date but it is 
not valid for any production after December 31 of the model year for 
which it is issued. No certificate will be issued after December 31 of 
the model year. A certificate of conformity for a component is valid 
starting with the indicated effective date but it is not valid for any 
production after the end of the production period for which it is 
issued.
    (b) The application must contain all the information required by 
this part and must not include false or incomplete statements or 
information (see Sec.  1060.255).
    (c) We may ask you to include less information than we specify in 
this subpart as long as you maintain all the information required by 
Sec.  1060.250. For example, equipment manufacturers might use only 
components that are certified by other companies to meet applicable 
emission standards, in which case we would not require submission of 
emission data already submitted by the component manufacturer.
    (d) You must use good engineering judgment for all decisions related 
to your application (see 40 CFR 1068.5).
    (e) An authorized representative of your company must approve and 
sign the application.
    (f) See Sec.  1060.255 for provisions describing how we will process 
your application.
    (g) We may specify streamlined procedures for small-volume equipment 
manufacturers.



Sec.  1060.202  What are the certification requirements related
to the general standards in Sec.  1060.101?

    Equipment manufacturers must ensure that their equipment is 
certified with respect to the general standards specified in Sec.  
1060.101(f) as follows:
    (a) If Sec.  1060.5 requires you to certify your equipment to any of 
the emission standards specified in Sec. Sec.  1060.102 through 
1060.105, describe in your application for certification how you will 
meet the general standards specified in Sec.  1060.101(f).
    (b) If Sec.  1060.5 does not require you to certify your equipment 
to any of the emission standards specified in Sec. Sec.  1060.102 
through 1060.105, your equipment is deemed to be certified with respect 
to the general standards specified in Sec.  1060.101(f) if you design 
and produce your equipment to meet those standards.
    (1) You must keep records as described in Sec.  1060.210. The other 
provisions of this part for certificate holders apply only as specified 
in Sec.  1060.5.
    (2) Your equipment is deemed to be certified only to the extent that 
it meets the general standards in Sec.  1060.101(f). Thus, it is a 
violation of 40 CFR 1068.101(a)(1) to introduce into U.S. commerce such 
equipment that does not meet applicable requirements under Sec.  
1060.101(f).
    (c) Instead of relying on paragraph (b) of this section, you may 
submit an application for certification and obtain a certificate from 
us. The provisions of this part apply in the same manner for 
certificates issued under this paragraph (c) as for any other 
certificate issued under this part.



Sec.  1060.205  What must I include in my application?

    This section specifies the information that must be in your 
application, unless we ask you to include less information under Sec.  
1060.201(c). We may require you to provide additional information to 
evaluate your application.
    (a) Describe the emission family's specifications and other basic 
parameters of the emission controls. Describe how you meet the running 
loss emission control requirements in Sec.  1060.104, if applicable. 
Describe how you meet any applicable equipment-based requirements of 
Sec.  1060.101(e) and (f). State whether you are requesting 
certification for gasoline or some other fuel type. List each 
distinguishable configuration in the emission family. For equipment that 
relies on one or more certified components, identify the EPA-issued 
emission family name for all the certified components.

[[Page 20]]

    (b) Describe the products you selected for testing and the reasons 
for selecting them.
    (c) Describe the test equipment and procedures that you used, 
including any special or alternate test procedures you used (see Sec.  
1060.501).
    (d) List the specifications of the test fuel to show that it falls 
within the required ranges specified in subpart F of this part.
    (e) State the equipment applications to which your certification is 
limited. For example, if your fuel system meets the emission 
requirements of this part applicable only to handheld Small SI 
equipment, state that the requested certificate would apply only for 
handheld Small SI equipment.
    (f) Identify the emission family's useful life.
    (g) Include the maintenance instructions you will give to the 
ultimate purchaser of each new nonroad engine (see Sec.  1060.125).
    (h) Include the emission-related installation instructions you will 
provide if someone else will install your component in a piece of 
nonroad equipment (see Sec.  1060.130).
    (i) Describe your emission control information label (see Sec. Sec.  
1060.135 and 1060.137).
    (j) Identify the emission standards or FELs to which you are 
certifying the emission family.
    (k) Present emission data to show your products meet the applicable 
emission standards. Note that Sec. Sec.  1060.235 and 1060.240 allow you 
to submit an application in certain cases without new emission data.
    (l) State that your product was tested as described in the 
application (including the test procedures, test parameters, and test 
fuels) to show you meet the requirements of this part. If you did not do 
the testing, identify the source of the data.
    (m) Report all valid test results. Also indicate whether there are 
test results from invalid tests or from any other tests of the emission-
data unit, whether or not they were conducted according to the test 
procedures of subpart F of this part. We may require you to report these 
additional test results. We may ask you to send other information to 
confirm that your tests were valid under the requirements of this part.
    (n) Unconditionally certify that all the products in the emission 
family comply with the requirements of this part, other referenced parts 
of the CFR, and the Clean Air Act.
    (o) Include good-faith estimates of U.S.-directed production 
volumes. Include a justification for the estimated production volumes if 
they are substantially different than actual production volumes in 
earlier years for similar models.
    (p) Include other applicable information, such as information 
required by other subparts of this part.
    (q) Name an agent for service located in the United States. Service 
on this agent constitutes service on you or any of your officers or 
employees for any action by EPA or otherwise by the United States 
related to the requirements of this part.

[73 FR 59298, Oct. 8, 2008, as amended at 86 FR 34529, June 29, 2021]



Sec.  1060.210  What records should equipment manufacturers keep
if they do not apply for certification?

    If you are an equipment manufacturer that does not need to obtain a 
certificate of conformity for your equipment as described in Sec.  
1060.5, you must keep the records specified in this section to document 
compliance with applicable requirements. We may review these records at 
any time. If we ask, you must send us these records within 30 days. You 
must keep these records for eight years from the end of the model year.
    (a) Identify your equipment models and the annual U.S.-directed 
production volumes for each model.
    (b) Identify the emission family names of the certificates that will 
cover your equipment, the part numbers of those certified components, 
and the names of the companies that hold the certificates. You must be 
able to identify this information for each piece of equipment you 
produce.
    (c) Describe how you comply with any emission-related installation 
instructions, labeling requirements, and the general standards in Sec.  
1060.101(e) and (f).

[[Page 21]]



Sec.  1060.225  How do I amend my application for certification?

    Before we issue a certificate of conformity, you may amend your 
application to include new or modified configurations, subject to the 
provisions of this section. After we have issued your certificate of 
conformity, you may send us an amended application requesting that we 
include new or modified configurations within the scope of the 
certificate, subject to the provisions of this section. You must amend 
your application if any changes occur with respect to any information 
included in your application.
    (a) You must amend your application before you take any of the 
following actions:
    (1) Add a configuration to an emission family. In this case, the 
configuration added must be consistent with other configurations in the 
emission family with respect to the criteria listed in Sec.  1060.230.
    (2) Change a configuration already included in an emission family in 
a way that may affect emissions, or change any of the components you 
described in your application for certification. This includes 
production and design changes that may affect emissions any time during 
the equipment's lifetime.
    (3) Modify an FEL for an emission family as described in paragraph 
(f) of this section. Note however that component manufacturers may not 
modify an FEL for their products unless they submit a separate 
application for a new emission family.
    (b) To amend your application for certification, send the following 
relevant information to the Designated Compliance Officer.
    (1) Describe in detail the addition or change in the configuration 
you intend to make.
    (2) Include engineering evaluations or data showing that the amended 
emission family complies with all applicable requirements in this part. 
You may do this by showing that the original emission data are still 
appropriate for showing that the amended family complies with all 
applicable requirements in this part.
    (3) If the original emission data for the emission family are not 
appropriate to show compliance for the new or modified configuration, 
include new test data showing that the new or modified configuration 
meets the requirements of this part.
    (4) Include any other information needed to make your application 
correct and complete.
    (c) We may ask for more test data or engineering evaluations. Within 
30 days after we make our request, you must provide the information or 
describe your plan for providing it in a timely manner.
    (d) For emission families already covered by a certificate of 
conformity, we will determine whether the existing certificate of 
conformity covers your new or modified configuration. You may ask for a 
hearing if we deny your request (see Sec.  1060.820).
    (e) For emission families already covered by a certificate of 
conformity, you may start producing the new or modified configuration 
anytime after you send us your amended application and before we make a 
decision under paragraph (d) of this section. However, if we determine 
that the affected configurations do not meet applicable requirements, we 
will notify you to cease production of the configurations and may 
require you to recall the equipment at no expense to the owner. Choosing 
to produce equipment under this paragraph (e) is deemed to be consent to 
recall all equipment that we determine do not meet applicable emission 
standards or other requirements and to remedy the nonconformity at no 
expense to the owner. If you do not provide information we request under 
paragraph (c) of this section within 30 days after we request it, you 
must stop producing the new or modified equipment.
    (f) If you hold a certificate of conformity for equipment and you 
have certified the fuel tank that you install in the equipment, you may 
ask us to approve a change to your FEL after the start of production. 
The changed FEL may not apply to equipment you have already introduced 
into U.S. commerce, except as described in this paragraph (f). If we 
approve a changed FEL after the start of production, you must identify 
the date or serial number for applying the new FEL. If you identify

[[Page 22]]

this by month and year, we will consider that a lowered FEL applies on 
the last day of the month and a raised FEL applies on the first day of 
the month. You may ask us to approve a change to your FEL in the 
following cases:
    (1) You may ask to raise your FEL for your emission family at any 
time. In your request, you must show that you will still be able to meet 
the emission standards as specified in the exhaust standard-setting 
part. If you amend your application by submitting new test data to 
include a newly added or modified fuel tank configuration, as described 
in paragraph (b)(3) of this section, use the appropriate FELs with 
corresponding production volumes to calculate your production-weighted 
average FEL for the model year. In all other circumstances, you must use 
the higher FEL for the entire family to calculate your production-
weighted average FEL under subpart H of this part.
    (2) You may ask to lower the FEL for your emission family only if 
you have test data from production units showing that emissions are 
below the proposed lower FEL. The lower FEL applies only for units you 
produce after we approve the new FEL. Use the appropriate FELs with 
corresponding production volumes to calculate your production-weighted 
average FEL for the model year.
    (g) You may produce equipment or components as described in your 
amended application for certification and consider those equipment or 
components to be in a certified configuration if we approve a new or 
modified configuration during the model year or production period under 
paragraph (d) of this section. Similarly, you may modify in-use products 
as described in your amended application for certification and consider 
those products to be in a certified configuration if we approve a new or 
modified configuration at any time under paragraph (d) of this section. 
Modifying a new or in-use product to be in a certified configuration 
does not violate the tampering prohibition of 40 CFR 1068.101(b)(1), as 
long as this does not involve changing to a certified configuration with 
a higher family emission limit.
    (h) Component manufacturers may not change an emission family's FEL 
under any circumstances. Changing the FEL would require submission of a 
new application for certification.

[73 FR 59298, Oct. 8, 2008, as amended at 86 FR 34529, June 29, 2021]



Sec.  1060.230  How do I select emission families?

    (a) For purposes of certification, divide your product line into 
families of equipment (or components) that are expected to have similar 
emission characteristics throughout their useful life.
    (b) Group fuel lines into the same emission family if they are the 
same in all the following aspects:
    (1) Type of material including barrier layer.
    (2) Production method.
    (3) Types of connectors and fittings (material, approximate wall 
thickness, etc.) for fuel line assemblies certified together.
    (c) Group fuel tanks (or fuel systems including fuel tanks) into the 
same emission family if they are the same in all the following aspects:
    (1) Type of material, including any pigments, plasticizers, UV 
inhibitors, or other additives that are expected to affect control of 
emissions.
    (2) Production method.
    (3) Relevant characteristics of fuel cap design for fuel systems 
subject to diurnal emission requirements.
    (4) Gasket material.
    (5) Emission control strategy.
    (6) Family emission limit, if applicable.
    (d) Group other fuel-system components and equipment into the same 
emission family if they are the same in all the following aspects:
    (1) Emission control strategy and design.
    (2) Type of material (such as type of charcoal used in a carbon 
canister). This paragraph (d)(2) does not apply for materials that are 
unrelated to emission control performance.
    (3) The fuel systems meet the running loss emission standard based 
on the same type of compliance demonstration specified in Sec.  
1060.104(b), if applicable.
    (e) You may subdivide a group of equipment or components that are 
identical under paragraphs (b) through

[[Page 23]]

(d) of this section into different emission families if you show the 
expected emission characteristics are different during the useful life.
    (f) In unusual circumstances, you may group equipment or components 
that are not identical with respect to the things listed in paragraph 
(b) through (d) of this section into the same emission family if you 
show that their emission characteristics during the useful life will be 
similar. The provisions of this paragraph (f) do not exempt any engines 
or equipment from meeting all the applicable standards and requirements 
in subpart B of this part.
    (g) Emission families may include components used in multiple 
equipment categories. Such families are covered by a single certificate. 
For example, a single emission family may contain fuel tanks used in 
both Small SI equipment and Marine SI vessels.

[73 FR 59298, Oct. 8, 2008, as amended at 86 FR 34529, June 29, 2021]



Sec.  1060.235  What testing requirements apply for certification?

    This section describes the emission testing you must perform to show 
compliance with the emission standards in subpart B of this part.
    (a) Select an emission-data unit from each emission family for 
testing. If you are certifying with a family emission limit, you must 
test at least three emission-data units. In general, you must test a 
preproduction product that will represent actual production. However, 
for fuel tank permeation, you may test a tank with standardized geometry 
provided that it is made of the same material(s) and appropriate wall 
thickness. In general, the test procedures specify that components or 
systems be tested rather than complete equipment. For example, to 
certify your family of Small SI equipment, you would need to test a 
sample of fuel line for permeation emissions and a fuel tank for 
permeation emissions. Note that paragraph (e) of this section and Sec.  
1060.240 allow you in certain circumstances to certify without testing 
an emission-data unit from the emission family. Select test components 
that are most likely to exceed (or have emissions nearer to) the 
applicable emission standards as follows:
    (1) For fuel tanks, consider the following factors associated with 
higher emission levels:
    (i) Smallest average wall thickness (or barrier thickness, as 
appropriate).
    (ii) Greatest extent of pinch welds for tanks using barrier 
technologies.
    (iii) Greatest relative area of gasket material, especially if 
gaskets are made of high-permeation materials.
    (2) For fuel lines, consider the following factors associated with 
higher emission levels:
    (i) Smallest average wall thickness (or barrier thickness, as 
appropriate).
    (ii) Smallest inner diameter.
    (b) Test your products using the procedures and equipment specified 
in subpart F of this part.
    (c) You may not do maintenance on emission-data units.
    (d) We may perform confirmatory testing by measuring emissions from 
any of your products from the emission family, as follows:
    (1) You must supply your products to us if we choose to perform 
confirmatory testing. We may require you to deliver your test articles 
to a facility we designate for our testing.
    (2) If we measure emissions on one of your products, the results of 
that testing become the official emission results for the emission 
family. Unless we later invalidate these data, we may decide not to 
consider your data in determining if your emission family meets 
applicable requirements in this part.
    (e) You may ask to use carryover emission data from a previous 
production period instead of doing new tests, but only if all the 
following are true:
    (1) The emission family from the previous production period differs 
from the current emission family only with respect to production period, 
items identified in Sec.  1060.225(a), or other characteristics 
unrelated to emissions. We may waive the criterion in this paragraph 
(e)(1) for differences we determine not to be relevant.
    (2) The emission-data unit from the previous production period 
remains the appropriate emission-data unit under paragraph (b) of this 
section. For example, you may not carryover emission

[[Page 24]]

data for your family of nylon fuel tanks if you have added a thinner-
walled fuel tank than was tested previously.
    (3) The data show that the emission-data unit would meet all the 
requirements that apply to the emission family covered by the 
application for certification.
    (f) We may require you to test another unit of the same or different 
configuration in addition to the unit(s) tested under paragraph (b) of 
this section.
    (g) If you use an alternate test procedure under Sec.  1060.505, and 
later testing shows that such testing does not produce results that are 
equivalent to the procedures specified in this part, we may reject data 
you generated using the alternate procedure.

[73 FR 59298, Oct. 8, 2008, as amended at 86 FR 34529, June 29, 2021]



Sec.  1060.240  How do I demonstrate that my emission family 
complies with evaporative emission standards?

    (a) For purposes of certification, your emission family is 
considered in compliance with an evaporative emission standard in 
subpart B of this part if you do either of the following:
    (1) You have test results showing a certified emission level from 
the fuel tank or fuel line (as applicable) in the family are at or below 
the applicable standard.
    (2) You comply with design specifications as specified in paragraphs 
(d) through (f) of this section.
    (b) Your emission family is deemed not to comply if any fuel tank or 
fuel line representing that family has an official emission result above 
the standard.
    (c) Round each official emission result to the same number of 
decimal places as the emission standard.
    (d) You may demonstrate for certification that your emission family 
complies with the fuel tank permeation standards specified in Sec.  
1060.103 with any of the following control technologies:
    (1) A coextruded high-density polyethylene fuel tank with a 
continuous ethylene vinyl alcohol barrier layer (with not more than 40 
molar percent ethylene) making up at least 2 percent of the fuel tank's 
overall wall thickness with any of the following gasket and fuel-cap 
characteristics:
    (i) No nonmetal gaskets or fuel caps.
    (ii) All nonmetal gaskets and fuel caps made from low-permeability 
materials.
    (iii) Nonmetal gaskets and fuel caps that are not made from low-
permeability materials up to the following limits:
    (A) Gaskets with a total exposed surface area less than 0.25 percent 
of the total inside surface area of the fuel tank. For example, a fuel 
tank with an inside surface area of 0.40 square meters may use high-
permeation gasket material representing a surface area of up to 1,000 
mm\2\ (0.25% x \1/100\ x 0.40 m\2\ x 1,000,000 mm\2\/m\2\). Determine 
surface area based on the amount of material exposed to liquid fuel.
    (B) Fuel caps directly mounted to the fuel tank with the surface 
area of the fuel cap less than 3.0 percent of the total inside surface 
area of the fuel tank. Use the smallest inside cross-sectional area of 
the opening on which the cap is mounted as the fuel cap's surface area.
    (2) A metal fuel tank with the gasket and fuel-cap characteristics 
meeting the specifications in paragraphs (d)(1)(i) through (iii) of this 
section.
    (e) You may demonstrate for certification that your emission family 
complies with the diurnal emission standards specified in Sec.  1060.105 
with any of the following control technologies:
    (1) A Marine SI fuel tank sealed up to a positive pressure of 7.0 
kPa (1.0 psig); however, the fuel tank may contain air inlets that open 
when there is a vacuum pressure inside the tank.
    (2) A Marine SI fuel tank equipped with a passively purged carbon 
canister that meets the requirements of this paragraph (e)(2). The 
carbon must adsorb no more than 0.5 grams of water per gram of carbon at 
90% relative humidity and a temperature of 255 
[deg]C. The carbon granules must have a minimum mean diameter of 3.1 mm 
based on the procedures in ASTM D2862 (incorporated by reference in 
Sec.  1060.810). The carbon must also pass a dust attrition test based 
on ASTM D3802 (incorporated by reference in Sec.  1060.810), except that 
hardness is defined as the

[[Page 25]]

ratio of mean particle diameter before and after the test and the 
procedure must involve twenty \1/2\-inch steel balls and ten \3/4\-inch 
steel balls. Use good engineering judgment in the structural design of 
the carbon canister. The canister must have a volume compensator or some 
other device to prevent the carbon pellets from moving within the 
canister as a result of vibration or changing temperature. The canister 
must have a minimum working capacity as follows:
    (i) You may use the measurement procedures specified by the 
California Air Resources Board in Attachment 1 to TP-902 to show that 
canister working capacity is least 3.6 grams of vapor storage capacity 
per gallon of nominal fuel tank capacity (or 1.4 grams of vapor storage 
capacity per gallon of nominal fuel tank capacity for fuel tanks used in 
nontrailerable boats).
    (ii) You may produce canisters with a minimum carbon volume of 0.040 
liters per gallon of nominal fuel tank capacity (or 0.016 liters per 
gallon for fuel tanks used in nontrailerable boats). The carbon canister 
must have a minimum effective length-to-diameter ratio of 3.5 and the 
vapor flow must be directed with the intent of using the whole carbon 
bed. The carbon must have a minimum carbon working capacity of 90 grams 
per liter.
    (f) We may establish additional design certification options where 
we find that new test data demonstrate that the use of a different 
technology design will ensure compliance with the applicable emission 
standards.
    (g) You may not establish a family emission limit below the emission 
standard for components certified based on design specifications under 
this section even if actual emission rates are much lower.

[73 FR 59298, Oct. 8, 2008, as amended at 86 FR 34530, June 29, 2021]



Sec.  1060.250  What records must I keep?

    (a) Organize and maintain the following records:
    (1) A copy of all applications and any summary information you send 
us.
    (2) Any of the information we specify in Sec.  1060.205 that you 
were not required to include in your application.
    (3) A detailed history of each emission-data unit. For each emission 
data unit, include all of the following:
    (i) The emission-data unit's construction, including its origin and 
buildup, steps you took to ensure that it represents production 
equipment, any components you built specially for it, and all the 
components you include in your application for certification.
    (ii) All your emission tests (valid and invalid), including the date 
and purpose of each test and documentation of test parameters described 
in subpart F of this part.
    (iii) All tests to diagnose emission control performance, giving the 
date and time of each and the reasons for the test.
    (iv) Any other significant events.
    (4) Annual production figures for each emission family divided by 
assembly plant.
    (5) Keep a list of equipment identification numbers for all the 
equipment you produce under each certificate of conformity.
    (b) Keep required data from emission tests and all other information 
specified in this section for eight years after we issue your 
certificate. If you use the same emission data or other information for 
a later model year, the eight-year period restarts with each year that 
you continue to rely on the information.
    (c) Store these records in any format and on any media as long as 
you can promptly send us organized, written records in English if we ask 
for them. You must keep these records readily available. We may review 
them at any time.

[73 FR 59298, Oct. 8, 2008, as amended at 86 FR 34530, June 29, 2021]



Sec.  1060.255  What decisions may EPA make regarding a certificate of conformity?

    (a) If we determine an application is complete and shows that the 
emission family meets all the requirements of this part and the Clean 
Air Act, we will issue a certificate of conformity for the emission 
family for that production period. We may make the approval subject to 
additional conditions.
    (b) We may deny an application for certification if we determine 
that an

[[Page 26]]

emission family fails to comply with emission standards or other 
requirements of this part or the Clean Air Act. We will base our 
decision on all available information. If we deny an application, we 
will explain why in writing.
    (c) In addition, we may deny your application or suspend or revoke a 
certificate of conformity if you do any of the following:
    (1) Refuse to comply with any testing or reporting requirements in 
this part.
    (2) Submit false or incomplete information. This includes doing 
anything after submitting an application that causes submitted 
information to be false or incomplete.
    (3) Cause any test data to become inaccurate.
    (4) Deny us from completing authorized activities (see 40 CFR 
1068.20). This includes a failure to provide reasonable assistance.
    (5) Produce equipment or components for importation into the United 
States at a location where local law prohibits us from carrying out 
authorized activities.
    (6) Fail to supply requested information or amend an application to 
include all equipment or components being produced.
    (7) Take any action that otherwise circumvents the intent of the 
Clean Air Act or this part.
    (d) We may void a certificate of conformity if you fail to keep 
records, send reports, or give us information as required under this 
part or the Clean Air Act. Note that these are also violations of 40 CFR 
1068.101(a)(2).
    (e) We may void a certificate of conformity if we find that you 
intentionally submitted false or incomplete information. This includes 
doing anything after submitting an application that causes submitted 
information to be false or incomplete.
    (f) If we deny an application or suspend, revoke, or void a 
certificate of conformity, you may ask for a hearing (see Sec.  
1060.820).

[86 FR 34530, June 29, 2021]



                Subpart D_Production Verification Testing



Sec.  1060.301  Manufacturer testing.

    (a) Using good engineering judgment, you must evaluate production 
samples to verify that equipment or components you produce are as 
specified in the certificate of conformity. This may involve testing 
using certification procedures or other measurements.
    (b) You must give us records to document your evaluation if we ask 
for them.



Sec.  1060.310  Supplying products to EPA for testing.

    Upon our request, you must supply a reasonable number of production 
samples to us for verification testing.



                        Subpart E_In-use Testing



Sec.  1060.401  General Provisions.

    We may perform in-use testing of any equipment or fuel-system 
components subject to the standards of this part.



                        Subpart F_Test Procedures



Sec.  1060.501  General testing provisions.

    (a) This subpart is addressed to you as a certifying manufacturer 
but it applies equally to anyone who does testing for you.
    (b) Unless we specify otherwise, the terms ``procedures'' and ``test 
procedures'' in this part include all aspects of testing, including the 
equipment specifications, calibrations, calculations, and other 
protocols and procedural specifications needed to measure emissions.
    (c) The specification for gasoline to be used for testing is given 
in 40 CFR 1065.710(b) or (c). Use the grade of gasoline specified for 
general testing. For testing specified in this part that requires 
blending gasoline and ethanol, blend this grade of neat gasoline with 
fuel-grade ethanol meeting the specifications of ASTM D4806 
(incorporated by reference in Sec.  1060.810). You do not need to 
measure the ethanol concentration of such blended fuels and may instead 
calculate the blended composition by assuming that the ethanol is pure 
and mixes perfectly with the base

[[Page 27]]

fuel. For example, if you mix 10.0 liters of fuel-grade ethanol with 
90.0 liters of gasoline, you may assume the resulting mixture is 10.0 
percent ethanol. You may use more pure or less pure ethanol if you can 
demonstrate that it will not affect your ability to demonstrate 
compliance with the applicable emission standards in subpart B of this 
part. Note that unless we specify otherwise, any references to gasoline-
ethanol mixtures containing a specified ethanol concentration means 
mixtures meeting the provisions of this paragraph (c). The following 
table summarizes test fuel requirements for the procedures specified in 
this subpart:

      Table 1 to Sec.   1060.501--Summary of Test Fuel Requirements
------------------------------------------------------------------------
            Procedure                  Reference         Test Fuel \a\
------------------------------------------------------------------------
Low-Emission Fuel Lines.........  Sec.   1060.510     CE10.
Nonroad Fuel Lines..............  Sec.   1060.515     CE10 \b\.
Cold-Weather Fuel Lines.........  Sec.   1060.515     Splash-blended
                                                       E10.
Fuel tank and fuel cap            Sec.   1060.520     Splash-blended
 permeation.                                           E10;
                                                       manufacturers may
                                                       instead use CE10.
Diurnal.........................  Sec.   1060.525     E0.
------------------------------------------------------------------------
\a\ Pre-mixed gasoline blends are specified in 40 CFR 1065.710(b).
  Splash-blended gasoline blends are a mix of neat gasoline specified in
  40 CFR 1065.710(c) and fuel-grade ethanol.
\b\ Different fuel specifications apply for fuel lines tested under 40
  CFR part 1051 for recreational vehicles, as described in 40 CFR
  1051.501.

    (d) Accuracy and precision of all temperature measurements must be 
1.0 [deg]C or better. If you use multiple sensors 
to measure differences in temperature, calibrate the sensors so they 
will be within 0.5 [deg]C of each other when they are in thermal 
equilibrium at a point within the range of test temperatures (use the 
starting temperature in Table 1 to Sec.  1060.525 unless this is not 
feasible).
    (e) Accuracy and precision of mass balances must be sufficient to 
ensure accuracy and precision of two percent or better for emission 
measurements for products at the maximum level allowed by the standard. 
The readability of the display may not be coarser than half of the 
required accuracy and precision. Examples are shown in the following 
table for a digital readout:

----------------------------------------------------------------------------------------------------------------
                                              Example 1               Example 2               Example 3
----------------------------------------------------------------------------------------------------------------
Applicable standard..................  1.5 g/m\2\/day.........  1.5 g/m\2\/day.........  15 g/m\2\/day.
Internal surface area................  1.15 m\2\..............  0.47 m\2\..............  0.015 m\2\.
Length of test.......................  14.0 days..............  14.0 days..............  14.1 days.
Maximum allowable mass change........  24.15 g................  9.87 g.................  3.173 g.
Required accuracy and precision......  0.483 g or better.    eq>0.197 g or better.    eq>0.0635 g or better.
Required readability.................  0.1 g or better........  0.1 g or better........  0.01 g or better.
----------------------------------------------------------------------------------------------------------------


[73 FR 59298, Oct. 8, 2008, as amended at 74 FR 8427, Feb. 24, 2009; 86 
FR 34530, June 29, 2021]



Sec.  1060.505  Other procedures.

    (a) Your testing. The procedures in this part apply for all testing 
you do to show compliance with emission standards, with certain 
exceptions listed in this section.
    (b) Our testing. These procedures generally apply for testing that 
we do to determine if your equipment complies with applicable emission 
standards. We may perform other testing as allowed by the Clean Air Act.
    (c) Exceptions. We may allow or require you to use procedures other 
than those specified in this part in the following cases:
    (1) You may request to use special procedures if your equipment 
cannot be tested using the specified procedures. We will approve your 
request if we determine that it would produce emission measurements that 
represent in-use operation and we determine that it can be used to show 
compliance with the requirements of the standard-setting part.
    (2) You may ask to use emission data collected using other 
procedures, such as those of the California Air Resources Board or the 
International Organization for Standardization. We will approve this 
only if you show us that

[[Page 28]]

using these other procedures does not affect your ability to show 
compliance with the applicable emission standards. This generally 
requires emission levels to be far enough below the applicable emission 
standards so any test differences do not affect your ability to state 
unconditionally that your equipment will meet all applicable emission 
standards when tested using the specified test procedures.
    (3) You may request to use alternate procedures that are equivalent 
to the specified procedures, or procedures that are more accurate or 
more precise than the specified procedures. We may perform tests with 
your equipment using either the approved alternate procedures or the 
specified procedures. See 40 CFR 1065.12 for a description of the 
information that is generally required for such alternate procedures.
    (4) The test procedures are specified for gasoline-fueled equipment. 
If your equipment will use another volatile liquid fuel instead of 
gasoline, use a test fuel that is representative of the fuel that will 
be used with the equipment in use. You may ask us to approve other 
changes to the test procedures to reflect the effects of using a fuel 
other than gasoline.
    (d) Approval. If we require you to request approval to use other 
procedures under paragraph (c) of this section, you may not use them 
until we approve your request.

[73 FR 59298, Oct. 8, 2008, as amended at 86 FR 34531, June 29, 2021]



Sec.  1060.510  How do I test EPA Low-Emission Fuel Lines for permeation emissions?

    For EPA Low-Emission Fuel Lines, measure emissions according to SAE 
J2260, which is incorporated by reference in Sec.  1060.810.

[74 FR 8427, Feb. 24, 2009]



Sec.  1060.515  How do I test EPA Nonroad Fuel Lines and EPA
Cold-Weather Fuel Lines for permeation emissions?

    Measure emission as follows for EPA Nonroad Fuel Lines and EPA Cold-
Weather Fuel Lines:
    (a) Prior to permeation testing, use good engineering judgment to 
precondition the fuel line by filling it with the fuel specified in this 
paragraph (a), sealing the openings, and soaking it for at least four 
weeks at 43 5 [deg]C or eight weeks at 23 5 [deg]C.
    (1) For EPA Nonroad Fuel Lines, use Fuel CE10, which is Fuel C as 
specified in ASTM D471 (incorporated by reference in Sec.  1060.810) 
blended with ethanol such that the blended fuel has 10.0 1.0 percent ethanol by volume.
    (2) For EPA Cold-Weather Fuel Lines, use gasoline blended with 
ethanol as described in Sec.  1060.501(c).
    (b) Drain the fuel line and refill it immediately with the fuel 
specified in paragraph (a) of this section. Be careful not to spill any 
fuel.
    (c) Except as specified in paragraph (d) of this section, measure 
fuel line permeation emissions using the equipment and procedures for 
weight-loss testing specified in SAE J30 or SAE J1527 (incorporated by 
reference in Sec.  1060.810). Start the measurement procedure within 8 
hours after draining and refilling the fuel line. Perform the emission 
test over a sampling period of 14 days. You may omit up to two daily 
measurements in any seven-day period. Determine your final emission 
result based on the average of measured values over the 14-day period. 
Maintain an ambient temperature of (232) [deg]C 
throughout the sampling period, except for intervals up to 30 minutes 
for daily weight measurements.
    (d) For fuel lines with a nominal inner diameter below 5.0 mm, you 
may alternatively measure fuel line permeation emissions using the 
equipment and procedures for weight-loss testing specified in SAE J2996 
(incorporated by reference in Sec.  1060.810). Determine your final 
emission result based on the average of measured values over the 14-day 
sampling period. Maintain an ambient temperature of (232) [deg]C throughout the sampling period, except for 
intervals up to 30 minutes for daily weight measurements.
    (e) Use good engineering judgment to test short fuel line segments. 
For example, you may need to join individual fuel line segments using 
proper connection fittings to achieve enough length

[[Page 29]]

and surface area for a proper measurement. Size the fuel reservoir 
appropriately for the tested fuel line.

[73 FR 59298, Oct. 8, 2008, as amended at 74 FR 8427, Feb. 24, 2009; 75 
FR 23027, Apr. 30, 2010; 80 FR 9116, Feb. 19, 2015; 86 FR 34531, June 
29, 2021; 88 FR 4669, Jan. 24, 2023]



Sec.  1060.520  How do I test fuel tanks for permeation emissions?

    Measure permeation emissions by weighing a sealed fuel tank before 
and after a temperature-controlled soak.
    (a) Preconditioning durability testing. Take the following steps 
before an emission test, in any order, if your emission control 
technology involves surface treatment or other post-processing 
treatments such as an epoxy coating:
    (1) Pressure cycling. Perform a pressure test by sealing the fuel 
tank and cycling it between +13.8 and -3.4 kPa (+2.0 and -0.5 psig) for 
10,000 cycles at a rate of 60 seconds per cycle. The purpose of this 
test is to represent environmental wall stresses caused by pressure 
changes and other factors (such as vibration or thermal expansion). If 
your fuel tank cannot be tested using the pressure cycles specified by 
this paragraph (a)(1), you may ask to use special test procedures under 
Sec.  1060.505.
    (2) UV exposure. Perform a sunlight-exposure test by exposing the 
fuel tank to an ultraviolet light of at least 24 W/m2 (0.40 W-hr/m2/min) 
on the fuel tank surface for at least 450 hours. Alternatively, the fuel 
tank may be exposed to direct natural sunlight for an equivalent period 
of time as long as you ensure that the fuel tank is exposed to at least 
450 daylight hours.
    (3) Slosh testing. Perform a slosh test by filling the fuel tank to 
40-50 percent of its capacity with the fuel specified in paragraph (e) 
of this section and rocking it at a rate of 15 cycles per minute until 
you reach one million total cycles. Use an angle deviation of +15[deg] 
to -15[deg] from level. Take steps to ensure that the fuel remains at 
40-50 percent of its capacity throughout the test run.
    (4) Cap testing. Perform durability cycles on fuel caps intended for 
use with handheld equipment by putting the fuel cap on and taking it off 
300 times. Tighten the fuel cap each time in a way that represents the 
typical in-use experience.
    (b) Preconditioning fuel soak. Take the following steps before an 
emission test:
    (1) Fill the fuel tank to its nominal capacity with the fuel 
specified in paragraph (e) of this section, seal it, and allow it to 
soak at (285) [deg]C for at least 20 weeks. 
Alternatively, the fuel tank may be soaked for at least 10 weeks at 
(435) [deg]C. You may count the time of the 
preconditioning steps in paragraph (a) of this section as part of the 
preconditioning fuel soak as long as the ambient temperature remains 
within the specified temperature range and the fuel tank continues to be 
at least 40 percent full throughout the test; you may add or replace 
fuel as needed to conduct the specified durability procedures. Void the 
test if you determine that the fuel tank has any kind of leak.
    (2) Empty the fuel tank and immediately refill it with the specified 
test fuel to its nominal capacity. Be careful not to spill any fuel.
    (3) [Reserved]
    (4) Allow the fuel tank and its contents to equilibrate to the 
temperatures specified in paragraph (d)(7) of this section. Seal the 
fuel tank as described in paragraph (b)(5) of this section once the fuel 
temperatures are stabilized at the test temperature. You must seal the 
fuel tank no more than eight hours after refueling. Until the fuel tank 
is sealed, take steps to minimize the vapor losses from the fuel tank, 
such as keeping the fuel cap loose on the fuel inlet or routing vapors 
through a vent hose.
    (5) Seal the fuel tank as follows:
    (i) If fuel tanks are designed for use with a filler neck such that 
the fuel cap is not directly mounted on the fuel tank, you may seal the 
fuel inlet with a nonpermeable covering.
    (ii) If fuel tanks are designed with fuel caps directly mounted on 
the fuel tank, take one of the following approaches:
    (A) Use a production fuel cap expected to have permeation emissions 
at least as high as the highest-emitting fuel cap that you expect to be 
used with fuel tanks from the emission family. It would generally be 
appropriate

[[Page 30]]

to consider an HDPE fuel cap with a nitrile rubber seal to be worst-
case.
    (B) You may seal the fuel inlet with a nonpermeable covering if you 
separately account for permeation emissions from the fuel cap. This may 
involve a separate measurement of permeation emissions from a worst-case 
fuel cap as described in Sec.  1060.521. This may also involve 
specifying a worst-case Family Emission Limit based on separately 
certified fuel caps as described in Sec.  1060.103(e).
    (C) If you use or specify a fuel gasket made of low-permeability 
material, you may seal the fuel inlet with a nonpermeable covering and 
calculate an emission rate for the complete fuel tank using a default 
value of 30 g/m\2\/day for the fuel cap (or 50 g/m\2\/day for testing at 
40 [deg]C). Use the smallest inside cross-sectional area of the opening 
on which the cap is mounted as the fuel cap's surface area.
    (iii) Openings that are not normally sealed on the fuel tank (such 
as hose-connection fittings and vents in fuel caps) may be sealed using 
nonpermeable fittings such as metal or fluoropolymer plugs.
    (iv) Openings for petcocks that are designed for draining fuel may 
be sealed using nonpermeable fittings such as metal or fluoropolymer 
plugs.
    (v) Openings for grommets may be sealed using nonpermeable fittings 
such as metal or fluoropolymer plugs.
    (vi) Rather than sealing a fuel tank with nonpermeable fittings, you 
may produce a fuel tank for testing without machining or stamping those 
holes.
    (c) Reference tank. A reference tank is required to correct for 
buoyancy effects that may occur during testing. Prepare the reference 
tank as follows:
    (1) Obtain a second tank whose total volume is within 5 percent of 
the test tank's volume. You may not use a tank that has previously 
contained fuel or any other contents that might affect its mass 
stability.
    (2) Fill the reference tank with enough glass beads (or other inert 
material) so the mass of the reference tank is approximately the same as 
the test tank when filled with fuel. Considering the performance 
characteristics of your balance, use good engineering judgment to 
determine how similar the mass of the reference tank needs to be to the 
mass of the test tank.
    (3) Ensure that the inert material is dry.
    (4) Seal the tank.
    (d) Permeation test run. To run the test, take the following steps 
after preconditioning:
    (1) Determine the fuel tank's internal surface area in square-
meters, accurate to at least three significant figures. You may use less 
accurate estimates of the surface area if you make sure not to 
overestimate the surface area.
    (2) Weigh the sealed test tank and record the weight. Place the 
reference tank on the balance and tare it so it reads zero. Place the 
sealed test tank on the balance and record the difference between the 
test tank and the reference tank. This value is Mo. Take this 
measurement directly after sealing the test tank as specified in 
paragraphs (b)(4) and (5) of this section.
    (3) Carefully place the test tank within a temperature-controlled 
room or enclosure. Do not spill or add any fuel.
    (4) Close the room or enclosure as needed to control temperatures 
and record the time. However, you may need to take steps to prevent an 
accumulation of hydrocarbon vapors in the room or enclosure that might 
affect the degree to which fuel permeates through the fuel tank. This 
might simply involve passive ventilation to allow fresh air exchanges.
    (5) Ensure that the measured temperature in the room or enclosure 
stays within the temperatures specified in paragraph (d)(6) of this 
section.
    (6) Leave the test tank in the room or enclosure for the duration of 
the test run, except that you may remove the tank for up to 30 minutes 
at a time to meet weighing requirements.
    (7) Hold the temperature of the room or enclosure at 28 2 [deg]C; measure and record the temperature at least 
daily. You may alternatively hold the temperature of the room or 
enclosure at 40 2 [deg]C to demonstrate compliance 
with the alternative standards specified in Sec.  1060.103(b).
    (8) Measure weight loss daily by retaring the balance using the 
reference tank and weighing the sealed test tank. Calculate the 
cumulative

[[Page 31]]

weight loss in grams for each measurement. Calculate the coefficient of 
determination, r\2\, based on a linear plot of cumulative weight loss 
vs. test days. Use the equation in 40 CFR 1065.602(k), with cumulative 
weight loss represented by yi and cumulative time represented 
by yref. The daily measurements must be at approximately the 
same time each day. You may omit up to two daily measurements in any 
seven-day period. Test for ten full days, then determine when to stop 
testing as follows:
    (i) You may stop testing after the measurement on the tenth day if 
r\2\ is at or above 0.95 or if the measured value is less than 50 
percent of the applicable standard. (Note that if a Family Emission 
Limit applies for the family, it is considered to be the applicable 
standard for that family.) This means that if you stop testing with an 
r\2\ below 0.95, you may not use the data to show compliance with a 
Family Emission Limit less than twice the measured value.
    (ii) If after ten days of testing your r\2\ value is below 0.95 and 
your measured value is more than 50 percent of the applicable standard 
in subpart B of this part, continue testing for a total of 20 days or 
until r\2\ is at or above 0.95. If r\2\ is not at or above 0.95 within 
20 days of testing, discontinue the test and precondition the test tank 
further until it has stabilized emission levels, then repeat the 
testing.
    (9) Record the difference in mass between the reference tank and the 
test tank for each measurement. This value is Mi, where ``i'' 
is a counter representing the number of days elapsed. Subtract 
Mi from Mo and divide the difference by the 
internal surface area of the fuel tank. Divide this g/m\2\ value by the 
number of test days (using at least two decimal places) to calculate the 
emission rate in g/m\2\/day. Example: If a fuel tank with an internal 
surface area of 0.720 m\2\ weighed 1.31 grams less than the reference 
tank at the beginning of the test and weighed 9.86 grams less than the 
reference tank after soaking for 10.03 days, the emission rate would be 
((-1.31 g) - (-9.86 g))/0.720 m\2\ /10.03 days = 1.1839 g/m\2\/day.
    (10) Determine your final emission result based on the cumulative 
weight loss measured on the final day of testing. Round this result to 
the same number of decimal places as the emission standard.
    (e) Fuel specifications. Use a low-level ethanol-gasoline blend as 
specified in Sec.  1060.501(c). As an alternative, you may use Fuel 
CE10, as described in Sec.  1060.515(a)(1).
    (f) Flow chart. The following figure presents a flow chart for the 
permeation testing described in this section:

[[Page 32]]

[GRAPHIC] [TIFF OMITTED] TR08OC08.078


[[Page 33]]



[73 FR 59298, Oct. 8, 2008, as amended at 75 FR 23027, Apr. 30, 2010; 80 
FR 9116, Feb. 19, 2015; 86 FR 34531, June 29, 2021; 88 FR 4669, Jan. 24, 
2023]



Sec.  1060.521  How do I test fuel caps for permeation emissions?

    If you measure a fuel tank's permeation emissions with a 
nonpermeable covering in place of the fuel cap under Sec.  
1060.520(b)(5)(ii)(B), you must separately measure permeation emissions 
from a fuel cap. You may show that your fuel tank and fuel cap meet 
emission standards by certifying them separately or by combining the 
separate measurements into a single emission rate based on the relative 
surface areas of the fuel tank and fuel cap. However, you may not 
combine these emission measurements if you test the fuel cap at a 
nominal temperature of 28 [deg]C and you test the fuel tank at 40 
[deg]C. Measure the fuel cap's permeation emissions as follows:
    (a) Select a fuel cap expected to have permeation emissions at least 
as high as the highest-emitting fuel cap that you expect to be used with 
fuel tanks from the emission family. Include a gasket that represents 
production models. If the fuel cap includes vent paths, seal these vents 
as follows:
    (1) If the vent path is through grooves in the gasket, you may use 
another gasket with no vent grooves if it is otherwise the same as a 
production gasket.
    (2) If the vent path is through the cap, seal any vents for testing.
    (b) Attach the fuel cap to a fuel tank with a capacity of at least 
one liter made of metal or some other impermeable material.
    (c) Use the procedures specified in Sec.  1060.520 to measure 
permeation emissions. Calculate emission rates using the smallest inside 
cross sectional area of the opening on which the cap is mounted as the 
fuel cap's surface area.



Sec.  1060.525  How do I test fuel systems for diurnal emissions?

    Use the procedures of this section to determine whether your fuel 
tanks meet diurnal emission standards as specified in Sec.  1060.105.
    (a) Use the following procedure to measure diurnal emissions:
    (1) Diurnal measurements are based on representative temperature 
cycles, as follows:
    (i) Diurnal fuel temperatures for marine fuel tanks that will be 
installed in nontrailerable boats must undergo repeat temperature swings 
of 2.6 [deg]C between nominal values of 27.6 and 30.2 [deg]C.
    (ii) Diurnal fuel temperatures for other installed marine fuel tanks 
must undergo repeat temperature swings of 6.6 [deg]C between nominal 
values of 25.6 and 32.2 [deg]C.
    (iii) For fuel tanks installed in equipment other than marine 
vessels, the following table specifies a profile of ambient 
temperatures:

 Table 1 to Sec.   1060.525--Diurnal Temperature Profiles for Nonmarine
                               Fuel Tanks
------------------------------------------------------------------------
                                                              Ambient
                                                            temperature
                      Time (hours)                           profile (
                                                              [deg]C)
------------------------------------------------------------------------
0.......................................................            22.2
1.......................................................            22.5
2.......................................................            24.2
3.......................................................            26.8
4.......................................................            29.6
5.......................................................            31.9
6.......................................................            33.9
7.......................................................            35.1
8.......................................................            35.4
9.......................................................            35.6
10......................................................            35.3
11......................................................            34.5
12......................................................            33.2
13......................................................            31.4
14......................................................            29.7
15......................................................            28.2
16......................................................            27.2
17......................................................            26.1
18......................................................            25.1
19......................................................            24.3
20......................................................            23.7
21......................................................            23.3
22......................................................            22.9
23......................................................            22.6
24......................................................            22.2
------------------------------------------------------------------------

    (2) Fill the fuel tank to 40 percent of nominal capacity with the 
gasoline specified in 40 CFR 1065.710(c) for general testing.
    (3) Install a vapor line from any vent ports that would not be 
sealed in the final in-use configuration. Use a length of vapor line 
representing the largest inside diameter and shortest length that would 
be expected with the range of in-use installations for the emission 
family.
    (4) If the fuel tank is equipped with a carbon canister, load the 
canister with

[[Page 34]]

butane or gasoline vapors to its canister working capacity as specified 
in Sec.  1060.240(e)(2)(i) and attach it to the fuel tank in a way that 
represents a typical in-use configuration. Purge the canister as follows 
to prepare for emission measurement:
    (i) For marine fuel tanks, perform a single heating and cooling 
cycle as specified in paragraph (a)(7) of this section without measuring 
emissions.
    (ii) For nonmarine fuel tanks, establish a characteristic purge 
volume by running an engine with the fuel tank installed to represent an 
in-use configuration. Measure the volume of air flowing through the 
canister while the engine operates for 30 minutes over repeat cycles of 
the appropriate duty cycle used for certifying the engine for exhaust 
emissions. Set up the loaded canister for testing by purging it with the 
characteristic purge volume from the engine simulation run.
    (5) Stabilize the fuel tank to be within 2.0 [deg]C of the nominal 
starting temperature specified in paragraph (a)(1) of this section. In 
the case of marine fuel tanks, install a thermocouple meeting the 
requirements of 40 CFR 86.107-96(e) in the approximate mid-volume of 
fuel and record the temperature at the end of the stabilization period 
to the nearest 0.1 [deg]C. For sealed fuel systems, replace the fuel cap 
once the fuel reaches equilibrium at the appropriate starting 
temperature.
    (6) Prepare the tank for mass measurement using one of the following 
procedures:
    (i) Place the stabilized fuel tank in a SHED meeting the 
specifications of 40 CFR 86.107-96(a)(1) that is equipped with a FID 
analyzer meeting the specifications of 40 CFR 1065.260. Take the 
following steps in sequence:
    (A) Purge the SHED.
    (B) Close and seal the SHED.
    (C) Zero and span the FID analyzer.
    (D) Within ten minutes of sealing the SHED, measure the initial 
hydrocarbon concentration. This is the start of the sampling period.
    (ii) If your testing configuration involves mass emissions at the 
standard of 2.0 grams or more, you may alternatively place the 
stabilized fuel tank in any temperature-controlled environment and 
establish mass emissions as a weight loss relative to a reference fuel 
tank using the procedure specified in Sec.  1060.520(d) instead of 
calculating it from changing hydrocarbon concentrations in the SHED.
    (7) Control temperatures as follows:
    (i) For marine fuel tanks, supply heat to the fuel tank for 
continuously increasing temperatures such that the fuel reaches the 
maximum temperature in 8 hours. Set the target temperature by adding the 
temperature swing specified in paragraph (a)(1) of this section to the 
recorded starting temperature. Hold the tank for approximately 60 
minutes at a temperature no less than 0.1 [deg]C below the target 
temperature. For example, if the recorded starting fuel temperature for 
a fuel tank that will be installed in a nontrailerable vessel is 27.1 
[deg]C, the target temperature is 29.7 [deg]C and the fuel must be 
stabilized for 60 minutes with fuel temperatures not falling below 29.6 
[deg]C. For EPA testing, fuel temperatures may not go 1.0 [deg]C above 
the target temperature at any point during the heating or stabilization 
sequence. Measure the hydrocarbon concentration in the SHED at the end 
of the high-temperature stabilization period. Calculate the diurnal 
emissions for this heating period based on the change in hydrocarbon 
concentration over this sampling period. Allow the fuel temperature to 
cool sufficiently to stabilize again at the starting temperature without 
emission sampling. Repeat the heating and measurement sequence for three 
consecutive days, starting each heating cycle no more than 26 hours 
after the previous start.
    (ii) For nonmarine fuel tanks, follow the air temperature trace from 
paragraph (a)(1)(iii) of this section for three consecutive 24-hour 
periods. Measured temperatures must follow the profile with a maximum 
deviation of 1.7 [deg]C for any hourly measurement and an average 
temperature deviation not to exceed 1.0 [deg]C, where the average 
deviation is calculated using the absolute value of each measured 
deviation. Start measuring emissions when you start the temperature 
profile. The end of the first, second, and third emission sampling 
periods must occur 14406, 28806, and 43206 minutes, 
respectively, after starting the measurement procedure.

[[Page 35]]

    (8) Use the highest of the three emission levels to determine 
whether your fuel tank meets the diurnal emission standard.
    (9) For emission control technologies that rely on a sealed fuel 
system, you may omit the preconditioning steps in paragraph (a)(4) of 
this section and the last two 24-hour periods of emission measurements 
in paragraph (a)(7) of this section. For purposes of this paragraph (a), 
sealed fuel systems include those that rely on pressure-relief valves, 
limiting flow orifices, bladder fuel tanks, and volume-compensating air 
bags.
    (b) You may subtract your fuel tank's permeation emissions from the 
measured diurnal emissions if the fuel tank is preconditioned with 
diurnal test fuel as described in Sec.  1060.520(b) or if you use good 
engineering judgment to otherwise establish that the fuel tank has 
stabilized permeation emissions. Measure permeation emissions for 
subtraction as specified in Sec.  1060.520(c) and (d) before measuring 
diurnal emissions, except that the permeation measurement must be done 
with diurnal test fuel at 282 [deg]C. Use 
appropriate units and corrections to subtract the permeation emissions 
from the fuel tank during the diurnal emission test. You may not 
subtract a greater mass of emissions under this paragraph (b) than the 
fuel tank would emit based on meeting the applicable emission standard 
for permeation.

[80 FR 9117, Feb. 19, 2015, as amended at 86 FR 34531, June 29, 2021]



                 Subpart G_Special Compliance Provisions



Sec.  1060.601  How do the prohibitions of 40 CFR 1068.101 apply 
with respect to the requirements of this part?

    (a) As described in Sec.  1060.1, fuel tanks and fuel lines that are 
used with or intended to be used with new nonroad engines or equipment 
are subject to evaporative emission standards under this part. This 
includes portable marine fuel tanks and fuel lines and other fuel-system 
components associated with portable marine fuel tanks. Note that Sec.  
1060.1 specifies an implementation schedule based on the date of 
manufacture of nonroad equipment, so new fuel tanks and fuel lines are 
not subject to standards under this part if they will be installed for 
use in equipment built before the specified dates for implementing the 
appropriate standards, subject to the limitations in paragraph (b) of 
this section. Except as specified in paragraph (f) of this section, 
fuel-system components that are subject to permeation or diurnal 
emission standards under this part must be covered by a valid 
certificate of conformity before being introduced into U.S. commerce to 
avoid violating the prohibition of 40 CFR 1068.101(a). To the extent we 
allow it under the exhaust standard-setting part, fuel-system components 
may be certified with a family emission limit higher than the specified 
emission standard.
    (b) New replacement fuel tanks and fuel lines must meet the 
requirements of this part 1060 if they are intended to be used with 
nonroad engines or equipment regulated under this part 1060, as follows:
    (1) Applicability of standards between January 1, 2012 and December 
31, 2019. Manufacturers, distributors, retailers, and importers must 
clearly state on the packaging for all replacement components that could 
reasonably be used with nonroad engines how such components may be used 
consistent with the prohibition in paragraph (a) of this section. It is 
presumed that such components are intended for use with nonroad engines 
regulated under this part 1060 unless the components, or the packaging 
for such components, clearly identify appropriate restrictions. This 
requirement does not apply for components that are clearly not intended 
for use with fuels.
    (2) Applicability of standards after January 1, 2020. Starting 
January 1, 2020, it is presumed that replacement components will be used 
with nonroad engines regulated under this part if they can reasonably be 
used with such engines. Manufacturers, distributors, retailers, and 
importers are therefore obligated to take reasonable steps to ensure 
that any uncertified components are not used to replace certified 
components. This would require labeling the components and may also 
require restricting the sales and requiring the ultimate purchaser to 
agree to not use

[[Page 36]]

the components inappropriately. This paragraph (b)(2) does not apply for 
components that are clearly not intended for use with fuels.
    (3) Applicability of the tampering prohibition. If a fuel tank or 
fuel line needing replacement was certified to meet the emission 
standards in this part with a family emission limit below the otherwise 
applicable standard, the new replacement fuel tank or fuel line must be 
certified to current emission standards, but need not be certified with 
the same or lower family emission limit to avoid violating the tampering 
prohibition in 40 CFR 1068.101(b)(1).
    (c) [Reserved]
    (d) Manufacturers that generate or use evaporative emission credits 
related to Marine SI engines in 40 CFR part 1045 or Small SI engines in 
40 CFR part 1054 are subject to the emission standards for which they 
are generating or using evaporative emission credits. These engines or 
equipment must therefore be covered by a valid certificate of conformity 
showing compliance with emission-credit provisions before being 
introduced into U.S. commerce to avoid violating the prohibition of 40 
CFR 1068.101(a).
    (e) If there is no valid certificate of conformity for any given 
evaporative emission standard for new equipment, the manufacturers of 
the engine, equipment and fuel-system components are each liable for 
violations of the prohibited acts with respect to the fuel systems and 
fuel-system components they have introduced into U.S. commerce, 
including fuel systems and fuel-system components installed in engines 
or equipment at the time the engines or equipment are introduced into 
U.S. commerce.
    (f) If you manufacture fuel lines or fuel tanks that are subject to 
the requirements of this part as described in paragraph (a) of this 
section, 40 CFR 1068.101(a) does not prohibit you from shipping your 
products directly to an equipment manufacturer or another manufacturer 
from which you have received a written commitment to be responsible for 
certifying the components as required under this part 1060. This 
includes SHED-based certification of Small SI equipment as described in 
Sec.  1060.105. If you ship fuel lines or fuel tanks under this 
paragraph (f), you must include documentation that accompanies the 
shipped products identifying the name and address of the company 
receiving shipment and stating that the fuel lines or fuel tanks are 
exempt under the provisions of 40 CFR 1060.601(f).
    (g) If new evaporative emission standards apply in a given model 
year, your equipment in that model year must have fuel-system components 
that are certified to the new standards, except that you may continue to 
use up your normal inventory of earlier fuel-system components that were 
built before the date of the new or changed standards. For example, if 
your normal inventory practice is to keep on hand a one-month supply of 
fuel tanks based on your upcoming production schedules, and a new tier 
of standards starts to apply for the 2012 model year, you may order fuel 
tanks based on your normal inventory requirements late in the fuel tank 
manufacturer's 2011 model year and install those fuel tanks in your 
equipment, regardless of the date of installation. Also, if your model 
year starts before the end of the calendar year preceding new standards, 
you may use fuel-system components from the previous model year (or 
uncertified components if no standards were in place) for those units 
you produce before January 1 of the year that new standards apply. If 
emission standards do not change in a given model year, you may continue 
to install fuel-system components from the previous model year without 
restriction. You may not circumvent the provisions of 40 CFR 
1068.101(a)(1) by stockpiling fuel-system components that were built 
before new or changed standards take effect.
    (h) If equipment manufacturers hold certificates of conformity for 
their equipment but they use only fuel-system components that have been 
certified by other companies, they may satisfy their defect-reporting 
obligations by tracking the information described in 40 CFR 
1068.501(b)(1) related to possible defects, reporting this information 
to the appropriate component manufacturers, and keeping these

[[Page 37]]

records for eight years. Such equipment manufacturers will not be 
considered in violation of 40 CFR 1068.101(b)(6) for failing to perform 
investigations, make calculations, or submit reports to EPA as specified 
in 40 CFR 1068.501. See Sec.  1060.5(a).

[73 FR 59298, Oct. 8, 2008, as amended at 75 FR 23027, Apr. 30, 2010; 86 
FR 34532, June 29, 2021]



Sec.  1060.605  Exemptions from evaporative emission standards.

    (a) Except as specified in the exhaust standard-setting part and 
paragraph (b) of this section, equipment using an engine that is exempt 
from exhaust emission standards under the provisions in 40 CFR part 
1068, subpart C or D, is also exempt from the requirements of this part 
1060. For example, engines or equipment exempted from exhaust emission 
standards for purposes of national security do not need to meet 
evaporative emission standards. Also, any engine that is exempt from 
emission standards because it will be used solely for competition does 
not need to meet evaporative emission standards. Equipment that is 
exempt from all exhaust emission standards under the standard-setting 
part are also exempt from the requirements of this part 1060; however, 
this does not apply for engines that must meet a less stringent exhaust 
emission standard as a condition of the exemption.
    (b) Engines produced under the replacement-engine exemption in 40 
CFR 1068.240 must use fuel-system components that meet the evaporative 
emission standards based on the model year of the engine being replaced 
subject to the provisions of 40 CFR 1068.265. If no evaporative emission 
standards applied at that time, no requirements related to evaporative 
emissions apply to the new engine. Installing a replacement engine does 
not change the applicability of requirements for the equipment into 
which the replacement engine is installed.
    (c) Engines or equipment that are temporarily exempt from EPA 
exhaust emission standards are also exempt from the requirements of this 
part 1060 for the same period as the exhaust exemption.
    (d) For equipment powered by more than one engine, all the engines 
installed in the equipment must be exempt from all applicable EPA 
exhaust emission standards for the equipment to also be exempt under 
paragraph (a) or (b) of this section.
    (e) In unusual circumstances, we may exempt components or equipment 
from the requirements of this part 1060 even if the equipment is powered 
by one or more engines that are subject to EPA exhaust emission 
standards. See 40 CFR part 1068. Such exemptions will be limited to:
    (1) Testing. See 40 CFR 1068.210.
    (2) National security. See 40 CFR 1068.225.
    (3) Economic hardship. See 40 CFR 1068.245 and 1068.250.
    (f) Evaporative emission standards generally apply based on the 
model year of the equipment, which is determined by the equipment's date 
of final assembly. However, in the first year of new emission standards, 
equipment manufacturers may apply evaporative emission standards based 
on the model year of the engine as shown on the engine's emission 
control information label. For example, for fuel tank permeation 
standards starting in 2012, equipment manufacturers may order a batch of 
2011 model year engines for installation in 2012 model year equipment, 
subject to the anti-stockpiling provisions of 40 CFR 1068.105(a). The 
equipment with the 2011 model year engines would not need to meet fuel 
tank permeation standards as long as the equipment is fully assembled by 
December 31, 2012.



Sec.  1060.610  Temporary exemptions for manufacturing and assembling
equipment and fuel-system components.

    (a) If you are a certificate holder, you may ship components or 
equipment requiring further assembly between two of your facilities, 
subject to the provisions of this paragraph (a). Unless we approve 
otherwise, you must maintain ownership and control of the products until 
they reach their destination. We may allow for shipment where you do not 
maintain actual ownership and control of the engines (such as hiring a 
shipping company to transport the products) but only if you demonstrate 
that the products will be transported

[[Page 38]]

only according to your specifications. Notify us of your intent to use 
the exemption in this paragraph (a) in your application for 
certification, if applicable. Your exemption is effective when we grant 
your certificate. You may alternatively request an exemption in a 
separate submission; for example, this would be necessary if you will 
not be the certificate holder for the products in question. We may 
require you to take specific steps to ensure that such products are in a 
certified configuration before reaching the ultimate purchaser. Note 
that since this is a temporary exemption, it does not allow you to sell 
or otherwise distribute equipment in an uncertified configuration to 
ultimate purchasers. Note also that the exempted equipment remains new 
and subject to emission standards until its title is transferred to the 
ultimate purchaser or it otherwise ceases to be new.
    (b) If you certify equipment, you may ask us at the time of 
certification for an exemption to allow you to ship your equipment 
without a complete fuel system. We will generally approve an exemption 
under this paragraph (b) only if you can demonstrate that the exemption 
is necessary and that you will take steps to ensure that equipment 
assembly will be properly completed before reaching the ultimate 
purchaser. We may specify conditions that we determine are needed to 
ensure that shipping the equipment without such components will not 
result in the equipment operating with uncertified components or 
otherwise in an uncertified configuration. For example, we may require 
that you ship the equipment to manufacturers that are contractually 
obligated to install certain components. See 40 CFR 1068.261.

[86 FR 34532, June 29, 2021]



          Subpart H_Averaging, Banking, and Trading Provisions



Sec.  1060.701  Applicability.

    (a) You are allowed to comply with the emission standards in this 
part with evaporative emission credits only if the exhaust standard-
setting part explicitly allows it for evaporative emissions.
    (b) The following exhaust standard-setting parts allow some use of 
evaporative emission credits:
    (1) 40 CFR part 1045 for marine vessels.
    (2) 40 CFR part 1051 for recreational vehicles.
    (3) 40 CFR part 1054 for Small SI equipment.
    (c) As specified in 40 CFR part 1048, there is no allowance to 
generate or use emission credits with Large SI equipment.



Sec.  1060.705  How do I certify components to an emission level 
other than the standard under this part or use such components in
my equipment?

    As specified in this section, a fuel-system component may be 
certified to a family emission limit (FEL) instead of the otherwise 
applicable emission standard. Note that the exhaust standard-setting 
part may apply maximum values for an FEL (i.e., FEL caps).
    (a) Requirements for certifying component manufacturers. See subpart 
C of this part for instructions regarding the general requirements for 
certifying components.
    (1) When you submit your application for certification, indicate the 
FEL to which your components will be certified. This FEL will serve as 
the applicable standard for your component, and the equipment that uses 
the component. For example, when the regulations of this part use the 
phrase ``demonstrate compliance with the applicable emission standard'' 
it will mean ``demonstrate compliance with the FEL'' for your component.
    (2) You may not change the FEL for an emission family. To specify a 
different FEL for your components, you must send a new application for 
certification for a new emission family.
    (3) Unless your FEL is below all emission standards that could 
potentially apply, you must ensure that all equipment manufacturers that 
will use your component are aware of the limitations regarding the 
conditions under which they may use your component.
    (4) It is your responsibility to read the instructions relative to 
emission-credit provisions in the standard-setting parts identified in 
Sec.  1060.1.

[[Page 39]]

    (b) Requirements for equipment manufacturers. See subpart C of this 
part for instructions regarding your ability to rely on the component 
manufacturer's certificate.
    (1) The FEL of the component will serve as the applicable standard 
for your equipment.
    (2) You may not specify more than one FEL for an emission family at 
one time; however, you may change the FEL during the model year as 
described in Sec.  1060.225(f).
    (3) If the FEL is above the emission standard you must ensure that 
the exhaust standard-setting part allows you to use evaporative emission 
credits to comply with emission standards and that you will have an 
adequate source of evaporative emission credits. You must certify your 
equipment as specified in Sec.  1060.201 and the rest of subpart C of 
this part.



          Subpart I_Definitions and Other Reference Information



Sec.  1060.801  What definitions apply to this part?

    The following definitions apply to this part. The definitions apply 
to all subparts unless we note otherwise. All undefined terms have the 
meaning the Clean Air Act gives to them. The definitions follow:
    Accuracy and precision means the sum of accuracy and repeatability, 
as defined in 40 CFR 1065.1001. For example, if a measurement device is 
determined to have an accuracy of 1% and a 
repeatability of 2%, then its accuracy and 
precision would be 3%.
    Adjustable parameter has the meaning given in 40 CFR 1068.50.
    Applicable emission standard or applicable standard means an 
emission standard to which a fuel-system component is subject. 
Additionally, if a fuel-system component has been or is being certified 
to another standard or FEL, applicable emission standard means the FEL 
or other standard to which the fuel-system component has been or is 
being certified. This definition does not apply to subpart H of this 
part.
    Canister working capacity means the measured amount of hydrocarbon 
vapor that can be stored in a canister as specified in Sec.  
1060.240(e)(2)(i).
    Carbon working capacity means the measured amount of hydrocarbon 
vapor that can be stored in a given volume of carbon when tested 
according to ASTM D5228 (incorporated by reference in Sec.  1060.810). 
See Sec.  1060.240(e)(2)(ii).
    Certification means relating to the process of obtaining a 
certificate of conformity for an emission family that complies with the 
emission standards and requirements in this part.
    Certified emission level means the highest official emission result 
in an emission family.
    Clean Air Act means the Clean Air Act, as amended, 42 U.S.C. 7401-
7671q.
    Cold-weather equipment is limited to the following types of handheld 
equipment: Chainsaws, cut-off saws, clearing saws, brush cutters with 
engines at or above 40cc, commercial earth and wood drills, and ice 
augers. This includes earth augers if they are also marketed as ice 
augers.
    Configuration means a unique combination of hardware (material, 
geometry, and size) and calibration within an emission family. Units 
within a single configuration differ only with respect to normal 
production variability or factors unrelated to emissions.
    Date of manufacture, means one of the following with respect to 
equipment:
    (1) For outboard engines with under-cowl fuel tanks and for vessels 
equipped with outboard engines and installed fuel tanks, date of 
manufacture means the date on which the fuel tank is installed.
    (2) For all other equipment, date of manufacture has the meaning 
given in 40 CFR 1068.30.
    Days means calendar days unless otherwise specified. For example, 
when we specify working days we mean calendar days, excluding weekends 
and U.S. national holidays.
    Designated Compliance Officer means the Director, Gasoline Engine 
Compliance Center, U.S. Environmental Protection Agency, 2000 Traverwood 
Drive, Ann Arbor, MI 48105; [email protected].
    Detachable fuel line means a fuel line or fuel line assembly 
intended to be used with a portable nonroad fuel tank and which is 
connected by special fittings to the fuel tank and/or engine for

[[Page 40]]

easy disassembly. Fuel lines that require a wrench or other tools to 
disconnect are not considered detachable fuel lines. Fuel lines that are 
labeled or marketed as USCG Type B1 fuel line as specified in 33 CFR 
183.540 are not considered detachable fuel lines if they are sold to the 
ultimate purchaser without quick-connect fittings or similar hardware.
    Diurnal emissions means evaporative emissions that occur as a result 
of venting fuel tank vapors during daily temperature changes while the 
engine is not operating.
    Effective length-to-diameter ratio means the mean vapor path length 
of a carbon canister divided by the effective diameter of that vapor 
path. The effective diameter is the diameter of a circle with the same 
cross-sectional area as the average cross-sectional area of the carbon 
canister's vapor path.
    Emission control system means any device, system, or element of 
design that controls or reduces the regulated evaporative emissions from 
a piece of nonroad equipment.
    Emission-data unit means a fuel line, fuel tank, fuel system, or 
fuel-system component that is tested for certification. This includes 
components tested by EPA.
    Emission family has the meaning given in Sec.  1060.230.
    Emission-related maintenance means maintenance that substantially 
affects emissions or is likely to substantially affect emission 
deterioration.
    Equipment means vehicles, marine vessels, and other types of nonroad 
equipment that are subject to this part's requirements.
    Evaporative means relating to fuel emissions that result from 
permeation of fuel through the fuel-system materials or from ventilation 
of the fuel system.
    Exhaust standard-setting part means the part in the Code of Federal 
Regulations that contains exhaust emission standards for a particular 
piece of equipment (or the engine in that piece of equipment). For 
example, the exhaust standard-setting part for off-highway motorcycles 
is 40 CFR part 1051. Exhaust standard-setting parts may include 
evaporative emission requirements or describe how the requirements of 
this part 1060 apply.
    Exposed gasket surface area means the surface area of the gasket 
inside the fuel tank that is exposed to fuel or fuel vapor. For the 
purposes of calculating exposed surface area of a gasket, the thickness 
of the gasket and the outside dimension of the opening being sealed are 
used. Gasket overhang into the fuel tank should be ignored for the 
purpose of this calculation.
    Family emission limit (FEL) means an emission level declared by the 
manufacturer to serve in place of an otherwise applicable emission 
standard under an ABT program specified by the exhaust standard-setting 
part. The family emission limit must be expressed to the same number of 
decimal places as the emission standard it replaces. The family emission 
limit serves as the emission standard for the emission family with 
respect to all required testing.
    Fuel CE10 has the meaning given in Sec.  1060.515(a).
    Fuel line means hoses or tubing designed to contain liquid fuel. The 
exhaust standard-setting part may further specify which types of hoses 
and tubing are subject to the standards of this part.
    Fuel system means all components involved in transporting, metering, 
and mixing the fuel from the fuel tank to the combustion chamber(s), 
including the fuel tank, fuel tank cap, fuel pump, fuel filters, fuel 
lines, carburetor or fuel-injection components, and all fuel-system 
vents. In the case where the fuel tank cap or other components 
(excluding fuel lines) are directly mounted on the fuel tank, they are 
considered to be a part of the fuel tank.
    Fuel type means a general category of fuels such as gasoline or 
natural gas. There can be multiple grades within a single fuel type, 
such as premium gasoline, regular gasoline, or low-level ethanol-
gasoline blends.
    Gasoline means one of the following:
    (1) For in-use fuels, gasoline means fuel that is commonly and 
commercially know as gasoline, including ethanol blends.
    (2) For testing, gasoline has the meaning given in subpart F of this 
part.

[[Page 41]]

    Good engineering judgment means judgments made consistent with 
generally accepted scientific and engineering principles and all 
available relevant information. See 40 CFR 1068.5 for the administrative 
process we use to evaluate good engineering judgment.
    High-permeability material means any nonmetal material that does not 
qualify as low-permeability material.
    Installed marine fuel line means a fuel line designed for delivering 
fuel to a Marine SI engine that does not meet the definition of portable 
marine fuel line.
    Installed marine fuel tank means a fuel tank designed for delivering 
fuel to a Marine SI engine that does not meet the definition of portable 
marine fuel tanks.
    Large SI means relating to engines that are subject to evaporative 
emission standards in 40 CFR part 1048.
    Low-permeability material means, for gaskets, a material with 
permeation emission rates at or below 10 (g-mm)/m\2\/day when measured 
according to SAE J2659 (incorporated by reference in Sec.  1060.810), 
where the test temperature is 23 [deg]C, the test fuel is Fuel CE10, and 
testing immediately follows a four-week preconditioning soak with the 
test fuel.
    Manufacture means the physical and engineering process of designing, 
constructing, and assembling an engine, piece of nonroad equipment, or 
fuel-system components subject to the requirements of this part.
    Manufacturer has the meaning given in section 216(1) of the Clean 
Air Act (42 U.S.C. 7550(1)). In general, this term includes:
    (1) Any person who manufactures an engine or piece of nonroad 
equipment for sale in the United States or otherwise introduces a new 
nonroad engine or a piece of new nonroad equipment into U.S. commerce.
    (2) Any person who manufactures a fuel-system component for an 
engine subject to the requirements of this part as described in Sec.  
1060.1(a).
    (3) Importers who import such products into the United States.
    Marine SI means relating to vessels powered by engines that are 
subject to exhaust emission standards in 40 CFR part 1045.
    Marine vessel has the meaning given in 40 CFR Sec.  1045.801, which 
generally includes all nonroad equipment used as a means of 
transportation on water.
    Model year means one of the following things:
    (1) For equipment defined as ``new nonroad equipment'' under 
paragraph (1) of the definition of ``new nonroad equipment'' model year 
means one of the following:
    (i) Calendar year of production.
    (ii) Your annual new model production period if it is different than 
the calendar year. This must include January 1 of the calendar year for 
which the model year is named. It may not begin before January 2 of the 
previous calendar year and it must end by December 31 of the named 
calendar year.
    (2) For other equipment defined as ``new nonroad equipment'' under 
paragraph (2) of the definition of ``new nonroad equipment'' model year 
has the meaning given in the exhaust standard-setting part.
    (3) For other equipment defined as ``new nonroad equipment'' under 
paragraph (3) or (4) of the definition of ``new nonroad equipment'' 
model year means the model year of the engine as defined in the exhaust 
standard-setting part.
    New nonroad equipment means equipment meeting one or more of the 
following criteria:
    (1) Nonroad equipment for which the ultimate purchaser has never 
received the equitable or legal title. The equipment is no longer new 
when the ultimate purchaser receives this title or the product is placed 
into service, whichever comes first.
    (2) Nonroad equipment that is defined as new under the exhaust 
standard-setting part. (Note: equipment that is not defined as new under 
the exhaust standard-setting part may be defined as new under this 
definition of ``new nonroad equipment.'')
    (3) Nonroad equipment with an engine that becomes new (as defined in 
the exhaust standard-setting part) while installed in the equipment. The 
equipment is no longer new when it is subsequently placed into service. 
This

[[Page 42]]

paragraph (3) does not apply if the engine becomes new before being 
installed in the equipment.
    (4) Nonroad equipment not covered by a certificate of conformity 
issued under this part at the time of importation and manufactured after 
the requirements of this part start to apply (see Sec.  1060.1). The 
equipment is no longer new when it is subsequently placed into service. 
Importation of this kind of new nonroad equipment is generally 
prohibited by 40 CFR part 1068.
    Nominal capacity means a fuel tank's volume as specified by the fuel 
tank manufacturer, using at least two significant figures, based on the 
maximum volume of fuel the tank can hold with standard refueling 
techniques.
    Nonroad engine has the meaning we give in 40 CFR 1068.30. In general 
this means all internal-combustion engines except motor vehicle engines, 
stationary engines, engines used solely for competition, or engines used 
in aircraft. This part does not apply to all nonroad engines (see Sec.  
1060.1).
    Nonroad equipment means a piece of equipment that is powered by or 
intended to be powered by one or more nonroad engines. Note that 
Sec. Sec.  1060.5 and 1060.601 describes how we treat outboard engines, 
portable marine fuel tanks, and associated fuel-system components as 
nonroad equipment under this part 1060.
    Nontrailerable boat means a vessel whose length is 26.0 feet or 
more, or whose width is more than 8.5 feet.
    Official emission result means the measured emission rate for an 
emission-data unit.
    Placed into service means put into initial use for its intended 
purpose. Equipment does not qualify as being ``placed into service'' 
based on incidental use by a manufacturer or dealer.
    Portable marine fuel line means a detachable fuel line that is used 
or intended to be used to supply fuel to a marine engine during 
operation. This also includes any fuel line labeled or marketed at USCG 
Type B1 fuel line as specified in 33 CFR 183.540, whether or not it 
includes detachable connecting hardware; this is often called universal 
fuel line.
    Portable marine fuel tank means a portable fuel tank that is used or 
intended to be used to supply fuel to a marine engine during operation.
    Portable nonroad fuel tank means a fuel tank that meets each of the 
following criteria:
    (1) It has design features indicative of use in portable 
applications, such as a carrying handle and fuel line fitting that can 
be readily attached to and detached from a nonroad engine.
    (2) It has a nominal fuel capacity of 12 gallons or less.
    (3) It is designed to supply fuel to an engine while the engine is 
operating.
    (4) It is not used or intended to be used to supply fuel to a marine 
engine. Note that portable tanks excluded from this definition of 
``portable nonroad fuel tank'' under this paragraph (4) because of their 
use with marine engines are portable marine fuel tanks.
    Production period means the period in which a component or piece of 
equipment will be produced under a certificate of conformity. A given 
production period for an emission family may not include components 
certified using different test data. A production period may not exceed 
five years for certified components. Note that the definition of model 
year includes specifications related to production periods for which a 
certificate is valid for equipment.
    Recreational vehicle means vehicles that are subject to evaporative 
emission standards in 40 CFR part 1051. This generally includes engines 
that will be installed in recreational vehicles if the engines are 
certified separately under 40 CFR 1051.20.
    Relating to as used in this section means relating to something in a 
specific, direct manner. This expression is used in this section only to 
define terms as adjectives and not to broaden the meaning of the terms.
    Revoke has the meaning given in 40 CFR 1068.30. If we revoke a 
certificate or an exemption, you must apply for a new certificate or 
exemption before continuing to introduce the affected equipment into 
U.S. commerce.
    Round means to round numbers according to standard procedures as 
specified in 40 CFR 1065.1001.
    Running loss emissions means unburned fuel vapor that escapes from

[[Page 43]]

the fuel system to the ambient atmosphere while the engine is operating, 
excluding permeation emissions and diurnal emissions. Running loss 
emissions generally result from fuel-temperature increases caused by 
heat released from in-tank fuel pumps, fuel recirculation, or proximity 
to heat sources such as the engine or exhaust components.
    Sealed means lacking openings to the atmosphere that would allow a 
measurable amount of liquid or vapor to leak out under normal operating 
pressures or other pressures specified in this part. For example, you 
may generally establish a maximum value for operating pressures based on 
the highest pressure you would observe from an installed fuel tank 
during continuous equipment operation on a sunny day with ambient 
temperatures of 35 [deg]C. A fuel system may be considered to have no 
measurable leak if it does not release bubbles when held underwater at 
the identified tank pressure for 60 seconds. This determination presumes 
the use of good engineering judgment; for example, it would not be 
appropriate to test the fuel tank such that small leaks would avoid 
detection by collecting in a cavity created by holding the tank with a 
certain orientation. Sealed fuel systems may have openings for emission 
controls or for fuel lines needed to route fuel to the engine.
    Small SI means relating to engines that are subject to emission 
standards in 40 CFR part 1054.
    Structurally integrated nylon fuel tank means a fuel tank having all 
the following characteristics:
    (1) The fuel tank is made of a polyamide material that does not 
contain more than 50 percent by weight of a reinforcing glass fiber or 
mineral filler and does not contain more than 10 percent by weight of 
impact modified polyamides that use rubberized agents such as EPDM 
rubber.
    (2) The fuel tank must be used in a cut-off saw or chainsaw or be 
integrated into a major structural member where, as a single component, 
the fuel tank material is a primary structural/stress member for other 
major components such as the engine, transmission, or cutting 
attachment.
    Subchapter U means 40 CFR parts 1000 through 1299.
    Suspend has the meaning given in 40 CFR 1068.30. If we suspend a 
certificate, you may not introduce into U.S. commerce equipment from 
that emission family unless we reinstate the certificate or approve a 
new one. If we suspend an exemption, you may not introduce into U.S. 
commerce equipment that was previously covered by the exemption unless 
we reinstate the exemption.
    Tare means to use a container or other reference mass to zero a 
balance before weighing a sample. Generally, this means placing the 
container or reference mass on the balance, allowing it to stabilize, 
then zeroing the balance without removing the container or reference 
mass. This allows you to use the balance to determine the difference in 
mass between the sample and the container or reference mass.
    Test sample means the collection of fuel lines, fuel tanks, or fuel 
systems selected from the population of an emission family for emission 
testing. This may include certification testing or any kind of 
confirmatory testing.
    Test unit means a piece of fuel line, a fuel tank, or a fuel system 
in a test sample.
    Ultimate purchaser means, with respect to any new nonroad equipment, 
the first person who in good faith purchases such new nonroad equipment 
for purposes other than resale.
    Ultraviolet light means electromagnetic radiation with a wavelength 
between 300 and 400 nanometers.
    United States has the meaning given in 40 CFR 1068.30.
    U.S.-directed production volume means the amount of equipment, 
subject to the requirements of this part, produced by a manufacturer for 
which the manufacturer has a reasonable assurance that sale was or will 
be made to ultimate purchasers in the United States.
    Useful life means the period during which new nonroad equipment is 
required to comply with all applicable emission standards. See Sec.  
1060.101.
    Void has the meaning given in 40 CFR 1068.30. In general this means 
to invalidate a certificate or an exemption both retroactively and 
prospectively.
    Volatile liquid fuel means any fuel other than diesel or biodiesel 
that is a liquid at atmospheric pressure and has

[[Page 44]]

a Reid Vapor Pressure higher than 2.0 pounds per square inch.
    We (us, our) means the Administrator of the Environmental Protection 
Agency and any authorized representatives.
    Wintertime equipment means equipment using a wintertime engine, as 
defined in 40 CFR 1054.801. Note this definition applies only for Small 
SI equipment.

[73 FR 59298, Oct. 8, 2008, as amended at 75 FR 23027, Apr. 30, 2010; 86 
FR 34532, June 29, 2021; 88 FR 4669, Jan. 24, 2023]



Sec.  1060.805  What symbols, acronyms, and abbreviations 
does this part use?

    The following symbols, acronyms, and abbreviations apply to this 
part:

[deg] degree.
ASTM American Society for Testing and Materials.
C Celsius.
CFR Code of Federal Regulations.
EPA Environmental Protection Agency.
FEL family emission limit.
g gram.
gal gallon.
hr hour.
in inch.
kPa kilopascal.
kW kilowatt.
L liter.
m meter.
min minute.
mm millimeter.
psig pounds per square inch of gauge pressure.
SAE Society of Automotive Engineers.
SHED Sealed Housing for Evaporative Determination.
U.S. United States.
U.S.C. United States Code.
W watt.



Sec.  1060.810  What materials does this part reference?

    (a) Materials incorporated by reference. Certain material is 
incorporated by reference into this part with the approval of the 
Director of the Federal Register under 5 U.S.C. 552(a) and 1 CFR part 
51. To enforce any edition other than that specified in this section, a 
document must be published in the Federal Register and the material must 
be available to the public. All approved material is available for 
inspection at U.S. EPA, Air and Radiation Docket and Information Center, 
1301 Constitution Ave. NW., Room B102, EPA West Building, Washington, DC 
20460, (202) 202-1744, and is available from the sources listed below. 
It is also available for inspection at the National Archives and Records 
Administration (NARA). For information on the availability of this 
material at NARA, call 202-741-6030, or go to http://www.archives.gov/
federal_register/code_of_federal_regulations/ibr_locations.html.
    (b) ASTM International material. The following standards are 
available from ASTM International, 100 Barr Harbor Drive, P.O. Box C700, 
West Conshohocken, PA, 19428-2959, (610) 832-9585, or http://
www.astm.org/:
    (1) ASTM D471-06, Standard Test Method for Rubber Property--Effect 
of Liquids, approved October 1, 2006 (``ASTM D471''), IBR approved for 
Sec.  1060.515(a).
    (2) ASTM D2862-97 (Reapproved 2004), Standard Test Method for 
Particle Size Distribution of Granular Activated Carbon, approved April 
1, 2004 (``ASTM D2862''), IBR approved for Sec.  1060.240(e).
    (3) ASTM D3802-79 (Reapproved 2005), Standard Test Method for Ball-
Pan Hardness of Activated Carbon, approved October 1, 2005 (``ASTM 
D3802''), IBR approved for Sec.  1060.240(e).
    (4) ASTM D4806-07, Standard Specification for Denatured Fuel Ethanol 
for Blending with Gasolines for Use as Automotive Spark-Ignition Engine 
Fuel, approved July 15, 2007 (``ASTM D4806''), IBR approved for Sec.  
1060.501(c).
    (5) ASTM D5228-92 (Reapproved 2005), Standard Test Method for 
Determination of Butane Working Capacity of Activated Carbon, approved 
October 1, 2005 (``ASTM D5228''), IBR approved for Sec.  1060.801.
    (c) SAE International material. The following standards are 
available from SAE International, 400 Commonwealth Dr., Warrendale, PA 
15096-0001, (877) 606-7323 (U.S. and Canada) or (724) 776-4970 (outside 
the U.S. and Canada), or http://www.sae.org:
    (1) SAE J30, Fuel and Oil Hoses, Revised June 1998, IBR approved for 
Sec.  1060.515(c).

[[Page 45]]

    (2) SAE J1527, Marine Fuel Hoses, Revised February 1993, IBR 
approved for Sec.  1060.515(c).
    (3) SAE J2260, Nonmetallic Fuel System Tubing with One or More 
Layers, Revised November 2004, IBR approved for Sec.  1060.510.
    (4) SAE J2659, Test Method to Measure Fluid Permeation of Polymeric 
Materials by Speciation, Issued December 2003, IBR approved for Sec.  
1060.801.
    (5) SAE J2996, Surface Vehicle Recommended Practice, Small Diameter 
Fuel Line Permeation Test Procedure, Issued January 2013, IBR approved 
for Sec.  1060.515(d).
    (d) [Reserved]
    (e) American Boat and Yacht Council Material. The following 
documents are available from the American Boat and Yacht Council, 613 
Third Street, Suite 10, Annapolis, MD 21403 or (410) 990-4460 or http://
abycinc.org/:
    (1) ABYC H-25, Portable Marine Gasoline Fuel Systems, July 2010, IBR 
approved for Sec.  1060.105(f).
    (2) [Reserved]

[80 FR 9117, Feb. 19, 2015, as amended at 86 FR 34533, June 29, 2021]



Sec.  1060.815  What provisions apply to confidential information?

    The provisions of 40 CFR 1068.10 apply for information you consider 
confidential.

[86 FR 34533, June 29, 2021]



Sec.  1060.820  How do I request a hearing?

    (a) You may request a hearing under certain circumstances as 
described elsewhere in this part. To do this, you must file a written 
request, including a description of your objection and any supporting 
data, within 30 days after we make a decision.
    (b) For a hearing you request under the provisions of this part, we 
will approve your request if we find that your request raises a 
substantial factual issue.
    (c) If we agree to hold a hearing, we will use the procedures 
specified in 40 CFR part 1068, subpart G.



Sec.  1060.825  What reporting and recordkeeping requirements
apply under this part?

    (a) This part includes various requirements to submit and record 
data or other information. Unless we specify otherwise, store required 
records in any format and on any media and keep them readily available 
for eight years after you send an associated application for 
certification, or eight years after you generate the data if they do not 
support an application for certification. We may request these records 
at any time. You must promptly give us organized, written records in 
English if we ask for them. This paragraph (a) applies whether or not 
you rely on someone else to keep records on your behalf. We may require 
you to submit written records in an electronic format.
    (b) The regulations in Sec.  1060.255 and 40 CFR 1068.25 and 
1068.101 describe your obligation to report truthful and complete 
information. This includes information not related to certification. 
Failing to properly report information and keep the records we specify 
violates 40 CFR 1068.101(a)(2), which may involve civil or criminal 
penalties.
    (c) Send all reports and requests for approval to the Designated 
Compliance Officer (see Sec.  1060.801).
    (d) Any written information we require you to send to or receive 
from another company is deemed to be a required record under this 
section. Such records are also deemed to be submissions to EPA. We may 
require you to send us these records.
    (e) Under the Paperwork Reduction Act (44 U.S.C. 3501 et seq.), the 
Office of Management and Budget approves the reporting and recordkeeping 
specified in the applicable regulations in this chapter. The following 
items illustrate the kind of reporting and recordkeeping we require for 
products regulated under this part:
    (1) We specify the following requirements related to component and 
equipment certification in this part:
    (i) In Sec.  1060.20 we give an overview of principles for reporting 
information.
    (ii) In subpart C of this part we identify a wide range of 
information required to certify engines.
    (iii) In Sec.  1060.301 we require manufacturers to make components, 
engines, or equipment available for our testing if we make such a 
request, and to keep records related to evaluation of production samples 
for verifying that the

[[Page 46]]

products are as specified in the certificate of conformity.
    (iv) In Sec.  1060.505 we specify information needs for establishing 
various changes to published test procedures.
    (2) We specify the following requirements related to the general 
compliance provisions in 40 CFR part 1068:
    (i) In 40 CFR 1068.5 we establish a process for evaluating good 
engineering judgment related to testing and certification.
    (ii) In 40 CFR 1068.25 we describe general provisions related to 
sending and keeping information.
    (iii) In 40 CFR 1068.27 we require manufacturers to make equipment 
available for our testing or inspection if we make such a request.
    (iv) In 40 CFR 1068.105 we require equipment manufacturers to keep 
certain records related to duplicate labels from engine manufacturers.
    (v) [Reserved]
    (vi) In 40 CFR part 1068, subpart C, we identify several reporting 
and recordkeeping items for making demonstrations and getting approval 
related to various exemptions.
    (vii) In 40 CFR part 1068, subpart D, we identify several reporting 
and recordkeeping items for making demonstrations and getting approval 
related to importing equipment.
    (viii) In 40 CFR 1068.450 and 1068.455 we specify certain records 
related to testing production-line products in a selective enforcement 
audit.
    (ix) In 40 CFR 1068.501 we specify certain records related to 
investigating and reporting emission-related defects.
    (x) In 40 CFR 1068.525 and 1068.530 we specify certain records 
related to recalling nonconforming equipment.
    (xi) In 40 CFR part 1068, subpart G, we specify certain records for 
requesting a hearing.

[86 FR 34533, June 29, 2021]



PART 1065_ENGINE-TESTING PROCEDURES--Table of Contents



             Subpart A_Applicability and General Provisions

Sec.
1065.1 Applicability.
1065.2 Submitting information to EPA under this part.
1065.5 Overview of this part 1065 and its relationship to the standard-
          setting part.
1065.10 Other procedures.
1065.12 Approval of alternate procedures.
1065.15 Overview of procedures for laboratory and field testing.
1065.20 Units of measure and overview of calculations.
1065.25 Recordkeeping.

                   Subpart B_Equipment Specifications

1065.101 Overview.
1065.110 Work inputs and outputs, accessory work, and operator demand.
1065.120 Fuel properties and fuel temperature and pressure.
1065.122 Engine cooling and lubrication.
1065.125 Engine intake air.
1065.127 Exhaust gas recirculation.
1065.130 Engine exhaust.
1065.140 Dilution for gaseous and PM constituents.
1065.145 Gaseous and PM probes, transfer lines, and sampling system 
          components.
1065.150 Continuous sampling.
1065.170 Batch sampling for gaseous and PM constituents.
1065.190 PM-stabilization and weighing environments for gravimetric 
          analysis.
1065.195 PM-stabilization environment for in-situ analyzers.

                    Subpart C_Measurement Instruments

1065.201 Overview and general provisions.
1065.202 Data updating, recording, and control.
1065.205 Performance specifications for measurement instruments.

         Measurement of Engine Parameters and Ambient Conditions

1065.210 Work input and output sensors.
1065.215 Pressure transducers, temperature sensors, and dewpoint 
          sensors.

                        Flow-Related Measurements

1065.220 Fuel flow meter.
1065.225 Intake-air flow meter.
1065.230 Raw exhaust flow meter.
1065.240 Dilution air and diluted exhaust flow meters.
1065.245 Sample flow meter for batch sampling.
1065.247 Diesel exhaust fluid flow rate.
1065.248 Gas divider.

                   CO and CO2 Measurements

1065.250 Nondispersive infrared analyzer.

                        Hydrocarbon Measurements

1065.260 Flame ionization detector.
1065.265 Nonmethane cutter.
1065.266 Fourier transform infrared analyzer.

[[Page 47]]

1065.267 Gas chromatograph with a flame ionization detector.
1065.269 Photoacoustic analyzer for ethanol and methanol.

             NOX and N2O Measurements

1065.270 Chemiluminescent detector.
1065.272 Nondispersive ultraviolet analyzer.
1065.274 Zirconium dioxide (ZrO2) NOX analyzer.
1065.275 N2O measurement devices.

                       O2 Measurements

1065.280 Paramagnetic and magnetopneumatic O2 detection 
          analyzers.

                     Air-to-Fuel Ratio Measurements

1065.284 Zirconium dioxide (ZrO2) air-fuel ratio and O2 analyzer.

                             PM Measurements

1065.290 PM gravimetric balance.
1065.295 PM inertial balance for field-testing analysis.
1065.298 Correcting real-time PM measurement based on gravimetric PM 
          filter measurement for field-testing analysis.

                Subpart D_Calibrations and Verifications

1065.301 Overview and general provisions.
1065.303 Summary of required calibration and verifications.
1065.305 Verifications for accuracy, repeatability, and noise.
1065.307 Linearity verification.
1065.308 Continuous gas analyzer system-response and updating-recording 
          verification--for gas analyzers not continuously compensated 
          for other gas species.
1065.309 Continuous gas analyzer system-response and updating-recording 
          verification--for gas analyzers continuously compensated for 
          other gas species.

         Measurement of Engine Parameters and Ambient Conditions

1065.310 Torque calibration.
1065.315 Pressure, temperature, and dewpoint calibration.

                        Flow-Related Measurements

1065.320 Fuel-flow calibration.
1065.325 Intake-flow calibration.
1065.330 Exhaust-flow calibration.
1065.340 Diluted exhaust flow (CVS) calibration.
1065.341 CVS and PFD flow verification (propane check).
1065.342 Sample dryer verification.
1065.345 Vacuum-side leak verification.

                   CO and CO2 Measurements

1065.350 H2O interference verification for CO2 
          NDIR analyzers.
1065.355 H2O and CO2 interference verification for 
          CO NDIR analyzers.

                        Hydrocarbon Measurements

1065.360 FID optimization and verification.
1065.362 Non-stoichiometric raw exhaust FID O2 interference 
          verification.
1065.365 Nonmethane cutter penetration fractions.
1065.366 Interference verification for FTIR analyzers.
1065.369 H2O, CO, and CO2 interference verification for photoacoustic 
          alcohol analyzers.

             NOX and N2O Measurements

1065.370 CLD CO2 and H2O quench verification.
1065.372 NDUV analyzer HC and H2O interference verification.
1065.375 Interference verification for N2O analyzers.
1065.376 Chiller NO2 penetration.
1065.378 NO2-to-NO converter conversion verification.

                             PM Measurements

1065.390 PM balance verifications and weighing process verification.
1065.395 Inertial PM balance verifications.

        Subpart E_Engine Selection, Preparation, and Maintenance

1065.401 Test engine selection.
1065.405 Test engine preparation and maintenance.
1065.410 Maintenance limits for stabilized test engines.
1065.415 Durability demonstration.

    Subpart F_Performing an Emission Test Over Specified Duty Cycles

1065.501 Overview.
1065.510 Engine mapping.
1065.512 Duty cycle generation.
1065.514 Cycle-validation criteria for operation over specified duty 
          cycles.
1065.516 Sample system decontamination and preconditioning.
1065.518 Engine preconditioning.
1065.520 Pre-test verification procedures and pre-test data collection.
1065.525 Engine starting, restarting, and shutdown.
1065.526 Repeating of void modes or test intervals.
1065.530 Emission test sequence.
1065.543 Carbon balance error verification.
1065.545 Verification of proportional flow control for batch sampling.

[[Page 48]]

1065.546 Verification of minimum dilution ratio for PM batch sampling.
1065.550 Gas analyzer range verification and drift verification.
1065.590 PM sampling media (e.g., filters) preconditioning and tare 
          weighing.
1065.595 PM sample post-conditioning and total weighing.

              Subpart G_Calculations and Data Requirements

1065.601 Overview.
1065.602 Statistics.
1065.610 Duty cycle generation.
1065.630 Local acceleration of gravity.
1065.640 Flow meter calibration calculations.
1065.642 PDP, SSV, and CFV molar flow rate calculations.
1065.643 Carbon balance error verification calculations.
1065.644 Vacuum-decay leak rate.
1065.645 Amount of water in an ideal gas.
1065.650 Emission calculations.
1065.655 Chemical balances of fuel, DEF, intake air, and exhaust.
1065.659 Removed water correction.
1065.660 THC, NMHC, NMNEHC, CH4, and 
          C2H6 determination.
1065.665 THCE and NMHCE determination.
1065.667 Dilution air background emission correction.
1065.670 NOX intake-air humidity and temperature corrections.
1065.672 Drift correction.
1065.675 CLD quench verification calculations.
1065.680 Adjusting emission levels to account for infrequently 
          regenerating aftertreatment devices.
1065.690 Buoyancy correction for PM sample media.
1065.695 Data requirements.

    Subpart H_Engine Fluids, Test Fuels, Analytical Gases and Other 
                          Calibration Standards

1065.701 General requirements for test fuels.
1065.703 Distillate diesel fuel.
1065.705 Residual and intermediate residual fuel.
1065.710 Gasoline.
1065.715 Natural gas.
1065.720 Liquefied petroleum gas.
1065.725 High-level ethanol-gasoline blends.
1065.735 Diesel exhaust fluid.
1065.740 Lubricants.
1065.745 Coolants.
1065.750 Analytical gases.
1065.790 Mass standards.

                 Subpart I_Testing with Oxygenated Fuels

1065.801 Applicability.
1065.805 Sampling system.
1065.845 Response factor determination.
1065.850 Calculations.

    Subpart J_Field Testing and Portable Emission Measurement Systems

1065.901 Applicability.
1065.905 General provisions.
1065.910 PEMS auxiliary equipment for field testing.
1065.915 PEMS instruments.
1065.920 PEMS calibrations and verifications.
1065.925 PEMS preparation for field testing.
1065.930 Engine starting, restarting, and shutdown.
1065.935 Emission test sequence for field testing.
1065.940 Emission calculations.

          Subpart K_Definitions and Other Reference Information

1065.1001 Definitions.
1065.1005 Symbols, abbreviations, acronyms, and units of measure.
1065.1010 Incorporation by reference.

Subpart L_Methods for Unregulated and Special Pollutants and Additional 
                               Procedures

1065.1101 Applicability.
1065.1102 Semi-Volatile Organic Compounds
1065.1103 General provisions for SVOC measurement.
1065.1105 Sampling system design.
1065.1107 Sample media and sample system preparation; sampler assembly.
1065.1109 Post-test sampler disassembly and sample extraction.
1065.1111 Sample analysis.

                  Vanadium Sublimation In SCR Catalysts

1065.1113 General provisions related to vanadium sublimation 
          temperatures in SCR catalysts.
1065.1115 Reactor design and setup.
1065.1117 Reactor aging cycle for determination of vanadium sublimation 
          temperature.
1065.1119 Blank testing.
1065.1121 Vanadium sample dissolution and analysis in alumina capture 
          beds.

                              Smoke Opacity

1065.1123 General provisions for determining exhaust opacity.
1065.1125 Exhaust opacity measurement system.
1065.1127 Test procedure for determining percent opacity.

                    Accelerated Aftertreatment Aging

1065.1131 General provisions related to accelerated aging of 
          compression-ignition

[[Page 49]]

          aftertreatment for deterioration factor determination.
1065.1133 Application selection, data gathering, and analysis.
1065.1135 Determination of key aftertreatment system components.
1065.1137 Determination of thermal reactivity coefficient.
1065.1139 Aging cycle generation.
1065.1141 Facility requirements for engine-based aging stands.
1065.1143 Requirements for burner-based aging stands.
1065.1145 Execution of accelerated aging, cycle tracking, and cycle 
          validation criteria.

    Authority: 42 U.S.C. 7401-7671q.

    Source: 70 FR 40516, July 13, 2005, unless otherwise noted.



             Subpart A_Applicability and General Provisions



Sec.  1065.1  Applicability.

    (a) This part describes the procedures that apply to testing we 
require for the following engines or for vehicles using the following 
engines:
    (1) Locomotives we regulate under 40 CFR part 1033.
    (2) Heavy-duty highway engines we regulate under 40 CFR parts 86 and 
1036.
    (3) Nonroad compression-ignition engines we regulate under 40 CFR 
part 1039 and stationary diesel engines that are certified to the 
standards in 40 CFR part 1039 as specified in 40 CFR part 60, subpart 
IIII.
    (4) Marine compression-ignition engines we regulate under 40 CFR 
part 1042.
    (5) Marine spark-ignition engines we regulate under 40 CFR part 
1045.
    (6) Large nonroad spark-ignition engines we regulate under 40 CFR 
part 1048, and stationary engines that are certified to the standards in 
40 CFR part 1048 or as otherwise specified in 40 CFR part 60, subpart 
JJJJ.
    (7) Vehicles we regulate under 40 CFR part 1051 (such as snowmobiles 
and off-highway motorcycles) based on engine testing. See 40 CFR part 
1051, subpart F, for standards and procedures that are based on vehicle 
testing.
    (8) Small nonroad spark-ignition engines we regulate under 40 CFR 
part 1054 and stationary engines that are certified to the standards in 
40 CFR part 1054 as specified in 40 CFR part 60, subpart JJJJ.
    (b) The procedures of this part may apply to other types of engines, 
as described in this part and in the standard-setting part.
    (c) The term ``you'' means anyone performing testing under this part 
other than EPA.
    (1) This part is addressed primarily to manufacturers of engines, 
vehicles, equipment, and vessels, but it applies equally to anyone who 
does testing under this part for such manufacturers.
    (2) This part applies to any manufacturer or supplier of test 
equipment, instruments, supplies, or any other goods or services related 
to the procedures, requirements, recommendations, or options in this 
part.
    (d) Paragraph (a) of this section identifies the parts of the CFR 
that define emission standards and other requirements for particular 
types of engines. In this part, we refer to each of these other parts 
generically as the ''standard-setting part.'' For example, 40 CFR part 
1051 is always the standard-setting part for snowmobiles. Note that 
while 40 CFR part 86 is the standard-setting part for heavy-duty highway 
engines, this refers specifically to 40 CFR part 86, subpart A, and to 
certain portions of 40 CFR part 86, subpart N, as described in 40 CFR 
86.1301.
    (e) Unless we specify otherwise, the terms ``procedures'' and ``test 
procedures'' in this part include all aspects of engine testing, 
including the equipment specifications, calibrations, calculations, and 
other protocols and procedural specifications needed to measure 
emissions.
    (f) For vehicles, equipment, or vessels subject to this part and 
regulated under vehicle-based, equipment-based, or vessel-based 
standards, use good engineering judgment to interpret the term 
``engine'' in this part to include vehicles, equipment, or vessels, 
where appropriate.
    (g) For additional information regarding the test procedures in this 
part, visit our website at www.epa.gov, and in particular https://
www.epa.gov/vehicle-and-fuel-emissions-testing/engine-testing-
regulations.

[[Page 50]]

    (h) This part describes procedures and specifications for measuring 
an engine's exhaust emissions. While the measurements are geared toward 
engine-based measurements (in units of g/kW [middot] hr), many of these 
provisions apply equally to vehicle-based measurements (in units of g/
mile or g/kilometer). 40 CFR part 1066 describes the analogous 
procedures for vehicle-based emission measurements, and in many cases 
states that specific provisions of this part 1065 also apply for those 
vehicle-based measurements. Where material from this part 1065 applies 
for vehicle-based measurements under 40 CFR part 1066, it is sometimes 
necessary to include parenthetical statements in this part 1065 to 
properly cite secondary references that are different for vehicle-based 
testing. See 40 CFR part 1066 and the standard-setting part for 
additional information.
    (i) The following additional procedures apply as described in 
subpart L of this part:
    (1) Measuring brake-specific emissions of semi-volatile organic 
compounds, which are not subject to separate emission standards.
    (2) Identifying the threshold temperature for vanadium sublimation 
for SCR catalysts.
    (3) Measuring the smoke opacity of engine exhaust.
    (4) Aging aftertreatment devices in support of determining 
deterioration factors for certified compression-ignition engines.

[73 FR 37288, June 30, 2008, as amended at 73 FR 59321, Oct. 8, 2008; 75 
FR 23028, Apr. 30, 2010; 76 FR 37977, June 28, 2011; 76 FR 57437, Sept. 
15, 2011; 79 FR 23752, Apr. 28, 2014; 86 FR 34533, June 29, 2021; 88 FR 
4669, Jan. 24, 2023]



Sec.  1065.2  Submitting information to EPA under this part.

    (a) You are responsible for statements and information in your 
applications for certification, requests for approved procedures, 
selective enforcement audits, laboratory audits, production-line test 
reports, field test reports, or any other statements you make to us 
related to this part 1065. If you provide statements or information to 
someone for submission to EPA, you are responsible for these statements 
and information as if you had submitted them to EPA yourself.
    (b) In the standard-setting part and in 40 CFR 1068.101, we describe 
your obligation to report truthful and complete information and the 
consequences of failing to meet this obligation. See also 18 U.S.C. 1001 
and 42 U.S.C. 7413(c)(2). This obligation applies whether you submit 
this information directly to EPA or through someone else.
    (c) We may void any certificates or approvals associated with a 
submission of information if we find that you intentionally submitted 
false, incomplete, or misleading information. For example, if we find 
that you intentionally submitted incomplete information to mislead EPA 
when requesting approval to use alternate test procedures, we may void 
the certificates for all engine families certified based on emission 
data collected using the alternate procedures. This paragraph (c) would 
also apply if you ignore data from incomplete tests or from repeat tests 
with higher emission results.
    (d) We may require an authorized representative of your company to 
approve and sign the submission, and to certify that all the information 
submitted is accurate and complete. This includes everyone who submits 
information, including manufacturers and others.
    (e) See 40 CFR 1068.10 for provisions related to confidential 
information. Note however that under 40 CFR 2.301, emission data are 
generally not eligible for confidential treatment.
    (f) Nothing in this part should be interpreted to limit our ability 
under Clean Air Act section 208 (42 U.S.C. 7542) to verify that engines 
conform to the regulations.

[73 FR 37289, June 30, 2008, as amended at 75 FR 23028, Apr. 30, 2010; 
79 FR 23752, Apr. 28, 2014; 86 FR 34533, June 29, 2021]



Sec.  1065.5  Overview of this part 1065 and its relationship to
the standard-setting part.

    (a) This part specifies procedures that apply generally to measuring 
brake-specific emissions from various categories of engines. See subpart 
L of this part for measurement procedures for testing related to 
standards other

[[Page 51]]

than brake-specific emission standards. See the standard-setting part 
for directions in applying specific provisions in this part for a 
particular type of engine. Before using this part's procedures, read the 
standard-setting part to answer at least the following questions:
    (1) What duty cycles must I use for laboratory testing?
    (2) Should I warm up the test engine before measuring emissions, or 
do I need to measure cold-start emissions during a warm-up segment of 
the duty cycle?
    (3) Which exhaust constituents do I need to measure? Measure all 
exhaust constituents that are subject to emission standards, any other 
exhaust constituents needed for calculating emission rates, and any 
additional exhaust constituents as specified in the standard-setting 
part. Alternatively, you may omit the measurement of N2O and 
CH4 for an engine, provided it is not subject to an 
N2O or CH4 emission standard. If you omit the 
measurement of N2O and CH4, you must provide other 
information and/or data that will give us a reasonable basis for 
estimating the engine's emission rates.
    (4) Do any unique specifications apply for test fuels?
    (5) What maintenance steps may I take before or between tests on an 
emission-data engine?
    (6) Do any unique requirements apply to stabilizing emission levels 
on a new engine?
    (7) Do any unique requirements apply to test limits, such as ambient 
temperatures or pressures?
    (8) Is field testing required or allowed, and are there different 
emission standards or procedures that apply to field testing?
    (9) Are there any emission standards specified at particular engine-
operating conditions or ambient conditions?
    (10) Do any unique requirements apply for durability testing?
    (b) The testing specifications in the standard-setting part may 
differ from the specifications in this part. In cases where it is not 
possible to comply with both the standard-setting part and this part, 
you must comply with the specifications in the standard-setting part. 
The standard-setting part may also allow you to deviate from the 
procedures of this part for other reasons.
    (c) The following table shows how this part divides testing 
specifications into subparts:

       Table 1 of Sec.   1065.5--Description of Part 1065 Subparts
------------------------------------------------------------------------
                                          Describes these specifications
              This subpart                        or procedures
------------------------------------------------------------------------
Subpart A..............................  Applicability and general
                                          provisions.
Subpart B..............................  Equipment for testing.
Subpart C..............................  Measurement instruments for
                                          testing.
Subpart D..............................  Calibration and performance
                                          verifications for measurement
                                          systems.
Subpart E..............................  How to prepare engines for
                                          testing, including service
                                          accumulation.
Subpart F..............................  How to run an emission test
                                          over a predetermined duty
                                          cycle.
Subpart G..............................  Test procedure calculations.
Subpart H..............................  Fuels, engine fluids,
                                          analytical gases, and other
                                          calibration standards.
Subpart I..............................  Special procedures related to
                                          oxygenated fuels.
Subpart J..............................  How to test with portable
                                          emission measurement systems
                                          (PEMS).
Subpart L..............................  How to test for unregulated and
                                          special pollutants and to
                                          perform additional
                                          measurements related to
                                          certification.
------------------------------------------------------------------------


[73 FR 37289, June 30, 2008, as amended at 74 FR 56511, Oct. 30, 2009; 
88 FR 4669, Jan. 24, 2023]



Sec.  1065.10  Other procedures.

    (a) Your testing. The procedures in this part apply for all testing 
you do to show compliance with emission standards, with certain 
exceptions noted in this section. In some other sections in this part, 
we allow you to use other procedures (such as less precise or less 
accurate procedures) if they do not affect your ability to show that 
your engines comply with the applicable emission standards. This 
generally requires emission levels to be far enough below the applicable 
emission standards so that any errors caused by greater imprecision or 
inaccuracy do not affect your ability to state unconditionally that the 
engines meet all applicable emission standards.
    (b) Our testing. These procedures generally apply for testing that 
we do to determine if your engines comply with applicable emission 
standards. We may perform other testing as allowed by the Act.
    (c) Exceptions. We may allow or require you to use procedures other 
than

[[Page 52]]

those specified in this part in the following cases, which may apply to 
laboratory testing, field testing, or both. We intend to publicly 
announce when we allow or require such exceptions. All of the test 
procedures noted here as exceptions to the specified procedures are 
considered generically as ``other procedures.'' Note that the terms 
``special procedures'' and ``alternate procedures'' have specific 
meanings; ``special procedures'' are those allowed by Sec.  
1065.10(c)(2) and ``alternate procedures'' are those allowed by Sec.  
1065.10(c)(7).
    (1) The objective of the procedures in this part is to produce 
emission measurements equivalent to those that would result from 
measuring emissions during in-use operation using the same engine 
configuration as installed in a vehicle, equipment, or vessel. However, 
in unusual circumstances where these procedures may result in 
measurements that do not represent in-use operation, you must notify us 
if good engineering judgment indicates that the specified procedures 
cause unrepresentative emission measurements for your engines. Note that 
you need not notify us of unrepresentative aspects of the test procedure 
if measured emissions are equivalent to in-use emissions. This provision 
does not obligate you to pursue new information regarding the different 
ways your engine might operate in use, nor does it obligate you to 
collect any other in-use information to verify whether or not these test 
procedures are representative of your engine's in-use operation. If you 
notify us of unrepresentative procedures under this paragraph (c)(1), we 
will cooperate with you to establish whether and how the procedures 
should be appropriately changed to result in more representative 
measurements. While the provisions of this paragraph (c)(1) allow us to 
be responsive to issues as they arise, we would generally work toward 
making these testing changes generally applicable through rulemaking. We 
will allow reasonable lead time for compliance with any resulting change 
in procedures. We will consider the following factors in determining the 
importance of pursuing changes to the procedures:
    (i) Whether supplemental emission standards or other requirements in 
the standard-setting part address the type of operation of concern or 
otherwise prevent inappropriate design strategies.
    (ii) Whether the unrepresentative aspect of the procedures affects 
your ability to show compliance with the applicable emission standards.
    (iii) The extent to which the established procedures require the use 
of emission-control technologies or strategies that are expected to 
ensure a comparable degree of emission control under the in-use 
operation that differs from the specified procedures.
    (2) You may request to use special procedures if your engine cannot 
be tested using the specified procedures. For example, this may apply if 
your engine cannot operate on the specified duty cycle. In this case, 
tell us in writing why you cannot satisfactorily test your engine using 
this part's procedures and ask to use a different approach. We will 
approve your request if we determine that it would produce emission 
measurements that represent in-use operation and we determine that it 
can be used to show compliance with the requirements of the standard-
setting part. Where we approve special procedures that differ 
substantially from the specified procedures, we may preclude you from 
participating in averaging, banking, and trading with the affected 
engine families.
    (3) In a given model year, you may use procedures required for later 
model year engines without request. If you upgrade your testing facility 
in stages, you may rely on a combination of procedures for current and 
later model year engines as long as you can ensure, using good 
engineering judgment, that the combination you use for testing does not 
affect your ability to show compliance with the applicable emission 
standards.
    (4) In a given model year, you may ask to use procedures allowed for 
earlier model year engines. We will approve this only if you show us 
that using the procedures allowed for earlier model years does not 
affect your ability to show compliance with the applicable emission 
standards.

[[Page 53]]

    (5) You may ask to use emission data collected using other 
procedures, such as those of the California Air Resources Board or the 
International Organization for Standardization. We will approve this 
only if you show us that using these other procedures does not affect 
your ability to show compliance with the applicable emission standards.
    (6) During the 12 months following the effective date of any change 
in the provisions of this part 1065 (and 40 CFR part 1066 for vehicle 
testing), you may use data collected using procedures specified in the 
previously applicable version of this part 1065 (and 40 CFR part 1066 
for vehicle testing). This also applies for changes to test procedures 
specified in the standard-setting part to the extent that these changes 
do not correspond to new emission standards. This paragraph (c)(6) does 
not restrict the use of carryover certification data otherwise allowed 
by the standard-setting part.
    (7) You may request to use alternate procedures that are equivalent 
to the specified procedures, or procedures that are more accurate or 
more precise than the specified procedures. We may perform tests with 
your engines using either the approved alternate procedures or the 
specified procedures. The following provisions apply to requests for 
alternate procedures:
    (i) Applications. Follow the instructions in Sec.  1065.12.
    (ii) Submission. Submit requests in writing to the EPA Program 
Officer.
    (iii) Notification. We may approve your request by telling you 
directly, or we may issue guidance announcing our approval of a specific 
alternate procedure, which would make additional requests for approval 
unnecessary.
    (d) Advance approval. If we require you to request approval to use 
other procedures under paragraph (c) of this section, you may not use 
them until we approve your request.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37290, June 30, 2008; 
75 FR 23028, Apr. 30, 2010; 79 FR 23752, Apr. 28, 2014; 80 FR 9118, Feb. 
19, 2015; 81 FR 74162, Oct. 25, 2016; 88 FR 4670, Jan. 24, 2023]



Sec.  1065.12  Approval of alternate procedures.

    (a) To get approval for an alternate procedure under Sec.  
1065.10(c), send the EPA Program Officer an initial written request 
describing the alternate procedure and why you believe it is equivalent 
to the specified procedure. Anyone may request alternate procedure 
approval. This means that an individual engine manufacturer may request 
to use an alternate procedure. This also means that an instrument 
manufacturer may request to have an instrument, equipment, or procedure 
approved as an alternate procedure to those specified in this part. We 
may approve your request based on this information alone, whether or not 
it includes all the information specified in this section. Where we 
determine that your original submission does not include enough 
information for us to determine that the alternate procedure is 
equivalent to the specified procedure, we may ask you to submit 
supplemental information showing that your alternate procedure is 
consistently and reliably at least as accurate and repeatable as the 
specified procedure.
    (b) We may make our approval under this section conditional upon 
meeting other requirements or specifications. We may limit our approval, 
for example, to certain time frames, specific duty cycles, or specific 
emission standards. Based upon any supplemental information we receive 
after our initial approval, we may amend a previously approved alternate 
procedure to extend, limit, or discontinue its use. We intend to 
publicly announce alternate procedures that we approve.
    (c) Although we will make every effort to approve only alternate 
procedures that completely meet our requirements, we may revoke our 
approval of an alternate procedure if new information shows that it is 
significantly not equivalent to the specified procedure.
    If we do this, we will grant time to switch to testing using an 
allowed procedure, considering the following factors:
    (1) The cost, difficulty, and availability to switch to a procedure 
that we allow.

[[Page 54]]

    (2) The degree to which the alternate procedure affects your ability 
to show that your engines comply with all applicable emission standards.
    (3) Any relevant factors considered in our initial approval.
    (d) If we do not approve your proposed alternate procedure based on 
the information in your initial request, we may ask you to send 
additional information to fully evaluate your request. While we consider 
the information specified in this paragraph (d) and the statistical 
criteria of paragraph (e) of this section to be sufficient to 
demonstrate equivalence, it may not be necessary to include all the 
information or meet the specified statistical criteria. For example, 
systems that do not meet the statistical criteria in paragraph (e) of 
this section because they have a small bias toward high emission results 
could be approved since they would not adversely affect your ability to 
demonstrate compliance with applicable standards.
    (1) Theoretical basis. Give a brief technical description explaining 
why you believe the proposed alternate procedure should result in 
emission measurements equivalent to those using the specified procedure. 
You may include equations, figures, and references. You should consider 
the full range of parameters that may affect equivalence. For example, 
for a request to use a different NOX measurement procedure, 
you should theoretically relate the alternate detection principle to the 
specified detection principle over the expected concentration ranges for 
NO, NO2, and interference gases. For a request to use a 
different PM measurement procedure, you should explain the principles by 
which the alternate procedure quantifies particulate mass similarly to 
the specified procedures.
    (2) Technical description. Describe briefly any hardware or software 
needed to perform the alternate procedure. You may include dimensioned 
drawings, flowcharts, schematics, and component specifications. Explain 
any necessary calculations or other data manipulation.
    (3) Procedure execution. Describe briefly how to perform the 
alternate procedure and recommend a level of training an operator should 
have to achieve acceptable results.
    Summarize the installation, calibration, operation, and maintenance 
procedures in a step-by-step format. Describe how any calibration is 
performed using NIST-traceable standards or other similar standards we 
approve. Calibration must be specified by using known quantities and 
must not be specified as a comparison with other allowed procedures.
    (4) Data-collection techniques. Compare measured emission results 
using the proposed alternate procedure and the specified procedure, as 
follows:
    (i) Both procedures must be calibrated independently to NIST-
traceable standards or to other similar standards we approve.
    (ii) Include measured emission results from all applicable duty 
cycles. Measured emission results should show that the test engine meets 
all applicable emission standards according to specified procedures.
    (iii) Use statistical methods to evaluate the emission measurements, 
such as those described in paragraph (e) of this section.
    (e) Absent any other directions from us, use a t-test and an F-test 
calculated according to Sec.  1065.602 to evaluate whether your proposed 
alternate procedure is equivalent to the specified procedure. We may 
give you specific directions regarding methods for statistical analysis, 
or we may approve other methods that you propose. Such alternate methods 
may be more or less stringent than those specified in this paragraph 
(e). In determining the appropriate statistical criteria, we will 
consider the repeatability of measurements made with the reference 
procedure. For example, less stringent statistical criteria may be 
appropriate for measuring emission levels being so low that they 
adversely affect the repeatability of reference measurements. We 
recommend that you consult a statistician if you are unfamiliar with 
these statistical tests. Perform the tests as follows:
    (1) Repeat measurements for all applicable duty cycles at least 
seven times for each procedure. You may use laboratory duty cycles to 
evaluate field-testing procedures.

[[Page 55]]

    Be sure to include all available results to evaluate the precision 
and accuracy of the proposed alternate procedure, as described in Sec.  
1065.2.
    (2) Demonstrate the accuracy of the proposed alternate procedure by 
showing that it passes a two-sided t-test. Use an unpaired t-test, 
unless you show that a paired t-test is appropriate under both of the 
following provisions:
    (i) For paired data, the population of the paired differences from 
which you sampled paired differences must be independent. That is, the 
probability of any given value of one paired difference is unchanged by 
knowledge of the value of another paired difference. For example, your 
paired data would violate this requirement if your series of paired 
differences showed a distinct increase or decrease that was dependent on 
the time at which they were sampled.
    (ii) For paired data, the population of paired differences from 
which you sampled the paired differences must have a normal (i.e., 
Gaussian) distribution. If the population of paired difference is not 
normally distributed, consult a statistician for a more appropriate 
statistical test, which may include transforming the data with a 
mathematical function or using some kind of non-parametric test.
    (3) Show that t is less than the critical t value, tcrit, tabulated 
in Sec.  1065.602, for the following confidence intervals:
    (i) 90% for a proposed alternate procedure for laboratory testing.
    (ii) 95% for a proposed alternate procedure for field testing.
    (4) Demonstrate the precision of the proposed alternate procedure by 
showing that it passes an F-test. Use a set of at least seven samples 
from the reference procedure and a set of at least seven samples from 
the alternate procedure to perform an F-test. The sets must meet the 
following requirements:
    (i) Within each set, the values must be independent. That is, the 
probability of any given value in a set must be unchanged by knowledge 
of another value in that set. For example, your data would violate this 
requirement if a set showed a distinct increase or decrease that was 
dependent upon the time at which they were sampled.
    (ii) For each set, the population of values from which you sampled 
must have a normal (i.e., Gaussian) distribution. If the population of 
values is not normally distributed, consult a statistician for a more 
appropriate statistical test, which may include transforming the data 
with a mathematical function or using some kind of non-parametric test.
    (iii) The two sets must be independent of each other. That is, the 
probability of any given value in one set must be unchanged by knowledge 
of another value in the other set. For example, your data would violate 
this requirement if one value in a set showed a distinct increase or 
decrease that was dependent upon a value in the other set. Note that a 
trend of emission changes from an engine would not violate this 
requirement.
    (iv) If you collect paired data for the paired t-test in paragraph 
(e)(2) in this section, use caution when selecting sets from paired data 
for the F-test. If you do this, select sets that do not mask the 
precision of the measurement procedure. We recommend selecting such sets 
only from data collected using the same engine, measurement instruments, 
and test cycle.
    (5) Show that F is less than the critical F value, Fcrit, tabulated 
in Sec.  1065.602. If you have several F-test results from several sets 
of data, show that the mean F-test value is less than the mean critical 
F value for all the sets. Evaluate Fcrit, based on the following 
confidence intervals:
    (i) 90% for a proposed alternate procedure for laboratory testing.
    (ii) 95% for a proposed alternate procedure for field testing.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37290, June 30, 2008; 
79 FR 23752, Apr. 28, 2014; 88 FR 4670, Jan. 24, 2023]



Sec.  1065.15  Overview of procedures for laboratory and field testing.

    This section outlines the procedures to test engines that are 
subject to emission standards.
    (a) In the standard-setting part, we set brake-specific emission 
standards in g/(kW [middot] hr) (or g/(hp [middot] hr)), for the 
following constituents:
    (1) Total oxides of nitrogen, NOX.

[[Page 56]]

    (2) Hydrocarbon, HC, which may be expressed in the following ways:
    (i) Total hydrocarbon, THC.
    (ii) Nonmethane hydrocarbon, NMHC, which results from subtracting 
methane, CH4, from THC.
    (iii) Nonmethane-nonethane hydrocarbon, NMNEHC, which results from 
subtracting methane, CH4, and ethane, 
C2H6, from THC.
    (iv) Total hydrocarbon-equivalent, THCE, which results from 
adjusting THC mathematically to be equivalent on a carbon-mass basis.
    (v) Nonmethane hydrocarbon-equivalent, NMHCE, which results from 
adjusting NMHC mathematically to be equivalent on a carbon-mass basis.
    (3) Particulate matter, PM.
    (4) Carbon monoxide, CO.
    (5) Carbon dioxide, CO2.
    (6) Methane, CH4.
    (7) Nitrous oxide, N2O.
    (b) Note that some engines are not subject to standards for all the 
emission constituents identified in paragraph (a) of this section. Note 
also that the standard-setting part may include standards for pollutants 
not listed in paragraph (a) of this section.
    (c) We generally set brake-specific emission standards over test 
intervals and/or duty cycles, as follows:
    (1) Engine operation. Testing may involve measuring emissions and 
work in a laboratory-type environment or in the field, as described in 
paragraph (f) of this section. For most laboratory testing, the engine 
is operated over one or more duty cycles specified in the standard-
setting part. However, laboratory testing may also include non-duty 
cycle testing (such as simulation of field testing in a laboratory). For 
field testing, the engine is operated under normal in-use operation. The 
standard-setting part specifies how test intervals are defined for field 
testing. Refer to the definitions of ``duty cycle'' and ``test 
interval'' in Sec.  1065.1001. Note that a single duty cycle may have 
multiple test intervals and require weighting of results from multiple 
test intervals to calculate a composite brake-specific emissions value 
to compare to the standard.
    (2) Constituent determination. Determine the total mass of each 
constituent over a test interval by selecting from the following 
methods:
    (i) Continuous sampling. In continuous sampling, measure the 
constituent's concentration continuously from raw or dilute exhaust. 
Multiply this concentration by the continuous (raw or dilute) flow rate 
at the emission sampling location to determine the constituent's flow 
rate. Sum the constituent's flow rate continuously over the test 
interval. This sum is the total mass of the emitted constituent.
    (ii) Batch sampling. In batch sampling, continuously extract and 
store a sample of raw or dilute exhaust for later measurement. Extract a 
sample proportional to the raw or dilute exhaust flow rate. You may 
extract and store a proportional sample of exhaust in an appropriate 
container, such as a bag, and then measure NOX, HC, CO, 
CO2, CH4, N2O, and CH2O 
concentrations in the container after the test interval. You may deposit 
PM from proportionally extracted exhaust onto an appropriate substrate, 
such as a filter. In this case, divide the PM by the amount of filtered 
exhaust to calculate the PM concentration. Multiply batch sampled 
concentrations by the total (raw or dilute) flow from which it was 
extracted during the test interval. This product is the total mass of 
the emitted constituent.
    (iii) Combined sampling. You may use continuous and batch sampling 
simultaneously during a test interval, as follows:
    (A) You may use continuous sampling for some constituents and batch 
sampling for others.
    (B) You may use continuous and batch sampling for a single 
constituent, with one being a redundant measurement. See Sec.  1065.201 
for more information on redundant measurements.
    (3) Work determination. Determine work over a test interval by one 
of the following methods:
    (i) Speed and torque. Synchronously multiply speed and brake torque 
to calculate instantaneous values for engine brake power. Sum engine 
brake power over a test interval to determine total work.
    (ii) Fuel consumed and brake-specific fuel consumption. Directly 
measure fuel consumed or calculate it with chemical

[[Page 57]]

balances of the fuel, intake air, and exhaust. To calculate fuel 
consumed by a chemical balance, you must also measure either intake-air 
flow rate or exhaust flow rate. Divide the fuel consumed during a test 
interval by the brake-specific fuel consumption to determine work over 
the test interval. For laboratory testing, calculate the brake-specific 
fuel consumption using fuel consumed and speed and torque over a test 
interval. For field testing, refer to the standard-setting part and 
Sec.  1065.915 for selecting an appropriate value for brake-specific 
fuel consumption.
    (d) Refer to Sec.  1065.650 for calculations to determine brake-
specific emissions.
    (e) The following figure illustrates the allowed measurement 
configurations described in this part 1065:

[[Page 58]]

[GRAPHIC] [TIFF OMITTED] TR15SE11.019

    (f) This part 1065 describes how to test engines in a laboratory-
type environment or in the field.
    (1) This affects test intervals and duty cycles as follows:

[[Page 59]]

    (i) For laboratory testing, you generally determine brake-specific 
emissions for duty-cycle testing by using an engine dynamometer in a 
laboratory or other environment. This typically consists of one or more 
test intervals, each defined by a duty cycle, which is a sequence of 
modes, speeds, and/or torques (or powers) that an engine must follow. If 
the standard-setting part allows it, you may also simulate field testing 
with an engine dynamometer in a laboratory or other environment.
    (ii) Field testing consists of normal in-use engine operation while 
an engine is installed in a vehicle, equipment, or vessel rather than 
following a specific engine duty cycle. The standard-setting part 
specifies how test intervals are defined for field testing.
    (2) The type of testing may also affect what test equipment may be 
used. You may use ``lab-grade'' test equipment for any testing. The term 
``lab-grade'' refers to equipment that fully conforms to the applicable 
specifications of this part. For some testing you may alternatively use 
``field-grade'' equipment. The term ``field-grade'' refers to equipment 
that fully conforms to the applicable specifications of subpart J of 
this part, but does not fully conform to other specifications of this 
part. You may use ``field-grade'' equipment for field testing. We also 
specify in this part and in the standard-setting parts certain cases in 
which you may use ``field-grade'' equipment for testing in a laboratory-
type environment. (Note: Although ``field-grade'' equipment is generally 
more portable than ``lab-grade'' test equipment, portability is not 
relevant to whether equipment is considered to be ``field-grade'' or 
``lab-grade''.)

[70 FR 40516, July 13, 2005, as amended at 73 FR 37290, June 30, 2008; 
75 FR 23028, Apr. 30, 2010; 76 FR 57437, Sept. 15, 2011; 79 FR 23753, 
Apr. 28, 2014; 81 FR 74162, Oct. 25, 2016]



Sec.  1065.20  Units of measure and overview of calculations.

    (a) System of units. The procedures in this part generally follow 
the International System of Units (SI), as detailed in NIST Special 
Publication 811, which we incorporate by reference in Sec.  1065.1010. 
The following exceptions apply:
    (1) We designate angular speed, fn, of an engine's 
crankshaft in revolutions per minute (r/min), rather than the SI unit of 
radians per second (rad/s). This is based on the commonplace use of r/
min in many engine dynamometer laboratories.
    (2) We designate brake-specific emissions in grams per kilowatt-hour 
(g/(kW [middot] hr)), rather than the SI unit of grams per megajoule (g/
MJ). In addition, we use the symbol hr to identify hour, rather than the 
SI convention of using h. This is based on the fact that engines are 
generally subject to emission standards expressed in g/kW [middot] hr. 
If we specify engine standards in grams per horsepower [middot] hour (g/
(hp [middot] hr)) in the standard-setting part, convert units as 
specified in paragraph (d) of this section.
    (3) We generally designate temperatures in units of degrees Celsius 
( [deg]C) unless a calculation requires an absolute temperature. In that 
case, we designate temperatures in units of Kelvin (K). For conversion 
purposes throughout this part, 0 [deg]C equals 273.15 K. Unless 
specified otherwise, always use absolute temperature values for 
multiplying or dividing by temperature.
    (b) Concentrations. This part does not rely on amounts expressed in 
parts per million. Rather, we express such amounts in the following SI 
units:
    (1) For ideal gases, [micro]mol/mol, formerly ppm (volume).
    (2) For all substances, cm\3\/m\3\, formerly ppm (volume).
    (3) For all substances, mg/kg, formerly ppm (mass).
    (c) Absolute pressure. Measure absolute pressure directly or 
calculate it as the sum of atmospheric pressure plus a differential 
pressure that is referenced to atmospheric pressure. Always use absolute 
pressure values for multiplying or dividing by pressure.
    (d) Units conversion. Use the following conventions to convert 
units:
    (1) Testing. You may record values and perform calculations with 
other units. For testing with equipment that involves other units, use 
the conversion factors from NIST Special Publication 811, as described 
in paragraph (a) of this section.

[[Page 60]]

    (2) Humidity. In this part, we identify humidity levels by 
specifying dewpoint, which is the temperature at which pure water begins 
to condense out of air. Use humidity conversions as described in Sec.  
1065.645.
    (3) Emission standards. If your standard is in g/(hp [middot] hr) 
units, convert kW to hp before any rounding by using the conversion 
factor of 1 hp (550 ft [middot] lbf/s) = 0.7456999 kW. Round the final 
value for comparison to the applicable standard.
    (e) Rounding. You are required to round certain final values, such 
as final emission values. You may round intermediate values when 
transferring data as long as you maintain at least six significant 
digits (which requires more than six decimal places for values less than 
0.1), or all significant digits if fewer than six digits are available. 
Unless the standard-setting part specifies otherwise, do not round other 
intermediate values. Round values to the number of significant digits 
necessary to match the number of decimal places of the applicable 
standard or specification as described in this paragraph (e). Note that 
specifications expressed as percentages have infinite precision (as 
described in paragraph (e)(7) of this section). Use the following 
rounding convention, which is consistent with ASTM E29 and NIST SP 811:
    (1) If the first (left-most) digit to be removed is less than five, 
remove all the appropriate digits without changing the digits that 
remain. For example, 3.141593 rounded to the second decimal place is 
3.14.
    (2) If the first digit to be removed is greater than five, remove 
all the appropriate digits and increase the lowest-value remaining digit 
by one. For example, 3.141593 rounded to the fourth decimal place is 
3.1416.
    (3) If the first digit to be removed is five with at least one 
additional non-zero digit following the five, remove all the appropriate 
digits and increase the lowest-value remaining digit by one. For 
example, 3.141593 rounded to the third decimal place is 3.142.
    (4) If the first digit to be removed is five with no additional non-
zero digits following the five, remove all the appropriate digits, 
increase the lowest-value remaining digit by one if it is odd and leave 
it unchanged if it is even. For example, 1.75 and 1.750 rounded to the 
first decimal place are 1.8; while 1.85 and 1.850 rounded to the first 
decimal place are also 1.8. Note that this rounding procedure will 
always result in an even number for the lowest-value digit.
    (5) This paragraph (e)(5) applies if the regulation specifies 
rounding to an increment other than decimal places or powers of ten (to 
the nearest 0.01, 0.1, 1, 10, 100, etc.). To round numbers for these 
special cases, divide the quantity by the specified rounding increment. 
Round the result to the nearest whole number as described in paragraphs 
(e)(1) through (4) of this section. Multiply the rounded number by the 
specified rounding increment. This value is the desired result. For 
example, to round 0.90 to the nearest 0.2, divide 0.90 by 0.2 to get a 
result of 4.5, which rounds to 4. Multiplying 4 by 0.2 gives 0.8, which 
is the result of rounding 0.90 to the nearest 0.2.
    (6) The following tables further illustrate the rounding procedures 
specified in this paragraph (e):

----------------------------------------------------------------------------------------------------------------
                                                                        Rounding increment
                    Quantity                     ---------------------------------------------------------------
                                                        10               1              0.1            0.01
----------------------------------------------------------------------------------------------------------------
3.141593........................................               0               3             3.1            3.14
123,456.789.....................................         123,460         123,457       123,456.8      123,456.79
5.500...........................................              10               6             5.5            5.50
4.500...........................................               0               4             4.5            4.50
----------------------------------------------------------------------------------------------------------------


----------------------------------------------------------------------------------------------------------------
                                                                        Rounding increment
                    Quantity                     ---------------------------------------------------------------
                                                        25               3              0.5            0.02
----------------------------------------------------------------------------------------------------------------
229.267.........................................             225             228           229.5          229.26
62.500..........................................              50              63            62.5           62.50
87.500..........................................             100              87            87.5           87.50
7.500...........................................               0               6             7.5            7.50
----------------------------------------------------------------------------------------------------------------


[[Page 61]]

    (7) This paragraph (e)(7) applies where we specify a limit or 
tolerance as some percentage of another value (such as 2% of a maximum concentration). You may show compliance 
with such specifications either by applying the percentage to the total 
value to calculate an absolute limit, or by converting the absolute 
value to a percentage by dividing it by the total value.
    (i) Do not round either value (the absolute limit or the calculated 
percentage), except as specified in paragraph (e)(7)(ii) of this 
section. For example, assume we specify that an analyzer must have a 
repeatability of 1% of the maximum concentration 
or better, the maximum concentration is 1059 ppm, and you determine 
repeatability to be 6.3 ppm. In this example, you 
could calculate an absolute limit of 10.59 ppm 
(1059 ppm x 0.01) or calculate that the 6.3 ppm repeatability is 
equivalent to a repeatability of 0.5949008498584%.
    (ii) Prior to July 1, 2013, you may treat tolerances (and equivalent 
specifications) specified in percentages as having fixed rather than 
infinite precision. For example, 2% would be equivalent to 1.51% to 
2.50% and 2.0% would be equivalent to 1.951% to 2.050%. Note that this 
allowance applies whether or not the percentage is explicitly specified 
as a percentage of another value.
    (8) You may use measurement devices that incorporate internal 
rounding, consistent with the provisions of this paragraph (e)(8). You 
may use devices that use any rounding convention if they report six or 
more significant digits. You may use devices that report fewer than six 
digits, consistent with good engineering judgment and the accuracy, 
repeatability, and noise specifications of this part. Note that this 
provision does not necessarily require you to perform engineering 
analysis or keep records.
    (f) Interpretation of ranges. Interpret a range as a tolerance 
unless we explicitly identify it as an accuracy, repeatability, 
linearity, or noise specification. See Sec.  1065.1001 for the 
definition of tolerance. In this part, we specify two types of ranges:
    (1) Whenever we specify a range by a single value and corresponding 
limit values above and below that value (such as X Y), target the associated control point to that single 
value (X). Examples of this type of range include ``10% of maximum pressure'', or ``(30 10) kPa''. In these examples, you would target the 
maximum pressure or 30 kPa, respectively.
    (2) Whenever we specify a range by the interval between two values, 
you may target any associated control point to any value within that 
range. An example of this type of range is ``(40 to 50) kPa''.
    (g) Scaling of specifications with respect to an applicable 
standard. Because this part 1065 is applicable to a wide range of 
engines and emission standards, some of the specifications in this part 
are scaled with respect to an engine's applicable standard or maximum 
power. This ensures that the specification will be adequate to determine 
compliance, but not overly burdensome by requiring unnecessarily high-
precision equipment. Many of these specifications are given with respect 
to a ``flow-weighted mean'' that is expected at the standard or during 
testing. Flow-weighted mean is the mean of a quantity after it is 
weighted proportional to a corresponding flow rate. For example, if a 
gas concentration is measured continuously from the raw exhaust of an 
engine, its flow-weighted mean concentration is the sum of the products 
(dry-to-wet corrected, if applicable) of each recorded concentration 
times its respective exhaust flow rate, divided by the sum of the 
recorded flow rates. As another example, the bag concentration from a 
CVS system is the same as the flow-weighted mean concentration, because 
the CVS system itself flow-weights the bag concentration. Refer to Sec.  
1065.602 for information needed to estimate and calculate flow-weighted 
means. Wherever a specification is scaled to a value based upon an 
applicable standard, interpret the standard to be the family emission 
limit if the engine is certified under an emission credit program in the 
standard-setting part.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37292, June 30, 2008; 
76 FR 57438, Sept. 15, 2011; 79 FR 23753, Apr. 28, 2014]



Sec.  1065.25  Recordkeeping.

    (a) The procedures in this part include various requirements to 
record

[[Page 62]]

data or other information. Refer to the standard-setting part and Sec.  
1065.695 regarding specific recordkeeping requirements.
    (b) You must promptly send us organized, written records in English 
if we ask for them. We may review them at any time.
    (c) We may waive specific reporting or recordkeeping requirements we 
determine to be unnecessary for the purposes of this part and the 
standard-setting part. Note that while we will generally keep the 
records required by this part, we are not obligated to keep records we 
determine to be unnecessary for us to keep. For example, while we 
require you to keep records for invalid tests so that we may verify that 
your invalidation was appropriate, it is not necessary for us to keep 
records for our own invalid tests.

[79 FR 23753, Apr. 28, 2014]



                   Subpart B_Equipment Specifications



Sec.  1065.101  Overview.

    (a) This subpart specifies equipment, other than measurement 
instruments, related to emission testing. The provisions of this subpart 
apply for all engine dynamometer testing where engine speeds and loads 
are controlled to follow a prescribed duty cycle. See subpart J of this 
part to determine which of the provisions of this subpart apply for 
field testing. This equipment includes three broad categories-
dynamometers, engine fluid systems (such as fuel and intake-air 
systems), and emission-sampling hardware.
    (b) Other related subparts in this part identify measurement 
instruments (subpart C), describe how to evaluate the performance of 
these instruments (subpart D), and specify engine fluids and analytical 
gases (subpart H).
    (c) Subpart J of this part describes additional equipment that is 
specific to field testing.
    (d) Figures 1 and 2 of this section illustrate some of the possible 
configurations of laboratory equipment. These figures are schematics 
only; we do not require exact conformance to them. Figure 1 of this 
section illustrates the equipment specified in this subpart and gives 
some references to sections in this subpart. Figure 2 of this section 
illustrates some of the possible configurations of a full-flow dilution, 
constant-volume sampling (CVS) system. Not all possible CVS 
configurations are shown.
    (e) Dynamometer testing involves engine operation over speeds and 
loads that are controlled to a prescribed duty cycle. Field testing 
involves measuring emissions over normal in-use operation of a vehicle 
or piece of equipment. Field testing does not involve operating an 
engine over a prescribed duty cycle.

[[Page 63]]

[GRAPHIC] [TIFF OMITTED] TR13JY05.012


[[Page 64]]


[GRAPHIC] [TIFF OMITTED] TR13JY05.013


[70 FR 40516, July 13, 2005, as amended at 73 FR 37292, June 30, 2008]



Sec.  1065.110  Work inputs and outputs, accessory work, and operator demand.

    (a) Work. Use good engineering judgment to simulate all engine work 
inputs and outputs as they typically would operate in use. Account for 
work inputs and outputs during an emission test by measuring them; or, 
if they are small, you may show by engineering analysis that 
disregarding them does not affect your ability to determine the net work 
output by more than 0.5% of the net expected work 
output over the test interval. Use equipment to simulate the specific 
types of work, as follows:
    (1) Shaft work. Use an engine dynamometer that is able to meet the 
cycle-validation criteria in Sec.  1065.514 over each applicable duty 
cycle.
    (i) You may use eddy-current and water-brake dynamometers for any 
testing that does not involve engine motoring, which is identified by 
negative torque commands in a reference duty cycle. See the standard 
setting part for reference duty cycles that are applicable to your 
engine.
    (ii) You may use alternating-current or direct-current motoring 
dynamometers for any type of testing.
    (iii) You may use one or more dynamometers.
    (iv) You may use any device that is already installed on a vehicle, 
equipment, or vessel to absorb work from the engine's output shaft(s). 
Examples of these types of devices include a vessel's propeller and a 
locomotive's generator.
    (2) Electrical work. Use one or more of the following to simulate 
electrical work:

[[Page 65]]

    (i) Use storage batteries or capacitors that are of the type and 
capacity installed in use.
    (ii) Use motors, generators, and alternators that are of the type 
and capacity installed in use.
    (iii) Use a resistor load bank to simulate electrical loads.
    (3) Pump, compressor, and turbine work. Use pumps, compressors, and 
turbines that are of the type and capacity installed in use. Use working 
fluids that are of the same type and thermodynamic state as normal in-
use operation.
    (b) Laboratory work inputs. You may supply any laboratory inputs of 
work to the engine. For example, you may supply electrical work to the 
engine to operate a fuel system, and as another example you may supply 
compressor work to the engine to actuate pneumatic valves. We may ask 
you to show by engineering analysis your accounting of laboratory work 
inputs to meet the criterion in paragraph (a) of this section.
    (c) Engine accessories. You must either install or account for the 
work of engine accessories required to fuel, lubricate, or heat the 
engine, circulate coolant to the engine, or to operate aftertreatment 
devices. Operate the engine with these accessories installed or 
accounted for during all testing operations, including mapping. If these 
accessories are not powered by the engine during a test, account for the 
work required to perform these functions from the total work used in 
brake-specific emission calculations. For air-cooled engines only, 
subtract externally powered fan work from total work. We may ask you to 
show by engineering analysis your accounting of engine accessories to 
meet the criterion in paragraph (a) of this section.
    (d) Engine starter. You may install a production-type starter.
    (e) Operator demand for shaft work. Operator demand is defined in 
Sec.  1065.1001. Command the operator demand and the dynamometer(s) to 
follow a prescribed duty cycle with set points for engine speed and 
torque as specified in Sec.  1065.512. Refer to the standard-setting 
part to determine the specifications for your duty cycle(s). Use a 
mechanical or electronic input to control operator demand such that the 
engine is able to meet the validation criteria in Sec.  1065.514 over 
each applicable duty cycle. Record feedback values for engine speed and 
torque as specified in Sec.  1065.512. Using good engineering judgment, 
you may improve control of operator demand by altering on-engine speed 
and torque controls. However, if these changes result in 
unrepresentative testing, you must notify us and recommend other test 
procedures under Sec.  1065.10(c)(1).
    (f) Other engine inputs. If your electronic control module requires 
specific input signals that are not available during dynamometer 
testing, such as vehicle speed or transmission signals, you may simulate 
the signals using good engineering judgment. Keep records that describe 
what signals you simulate and explain why these signals are necessary 
for representative testing.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37292, June 30, 2008]



Sec.  1065.120  Fuel properties and fuel temperature and pressure.

    (a) Use fuels as specified in the standard-setting part, or as 
specified in subpart H of this part if fuels are not specified in the 
standard-setting part.
    (b) If the engine manufacturer specifies fuel temperature and 
pressure tolerances and the location where they are to be measured, then 
measure the fuel temperature and pressure at the specified location to 
show that you are within these tolerances throughout testing.
    (c) If the engine manufacturer does not specify fuel temperature and 
pressure tolerances, use good engineering judgment to set and control 
fuel temperature and pressure in a way that represents typical in-use 
fuel temperatures and pressures.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37293, June 30, 2008]



Sec.  1065.122  Engine cooling and lubrication.

    (a) Engine cooling. Cool the engine during testing so its intake-
air, oil, coolant, block, and head temperatures are within their 
expected ranges for normal operation. You may use auxiliary coolers and 
fans.

[[Page 66]]

    (1) For air-cooled engines only, if you use auxiliary fans you must 
account for work input to the fan(s) according to Sec.  1065.110.
    (2) See Sec.  1065.125 for more information related to intake-air 
cooling.
    (3) See Sec.  1065.127 for more information related to exhaust gas 
recirculation cooling.
    (4) Measure temperatures at the manufacturer-specified locations. If 
the manufacturer does not specify temperature measurement locations, 
then use good engineering judgment to monitor intake-air, oil, coolant, 
block, and head temperatures to ensure that they are in their expected 
ranges for normal operation.
    (b) Forced cooldown. You may install a forced cooldown system for an 
engine and an exhaust aftertreatment device according to Sec.  
1065.530(a)(1).
    (c) Lubricating oil. Use lubricating oils specified in Sec.  
1065.740. For two-stroke engines that involve a specified mixture of 
fuel and lubricating oil, mix the lubricating oil with the fuel 
according to the manufacturer's specifications.
    (d) Coolant. For liquid-cooled engines, use coolant as specified in 
Sec.  1065.745.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37293, June 30, 2008]



Sec.  1065.125  Engine intake air.

    (a) Use the intake-air system installed on the engine or one that 
represents a typical in-use configuration. This includes the charge-air 
cooling and exhaust gas recirculation systems.
    (b) Measure temperature, humidity, and atmospheric pressure near the 
entrance of the furthest upstream engine or in-use intake system 
component. This would generally be near the engine's air filter, or near 
the inlet to the in-use air intake system for engines that have no air 
filter. For engines with multiple intakes, make measurements near the 
entrance of each intake.
    (1) Pressure. You may use a single shared atmospheric pressure meter 
as long as your laboratory equipment for handling intake air maintains 
ambient pressure at all intakes within 1 kPa of 
the shared atmospheric pressure. For engines with multiple intakes with 
separate atmospheric pressure measurements at each intake, use an 
average value for verifying compliance to Sec.  1065.520(b)(2).
    (2) Humidity. You may use a single shared humidity measurement for 
intake air as long as your equipment for handling intake air maintains 
dewpoint at all intakes to within 0.5 [deg]C of 
the shared humidity measurement. For engines with multiple intakes with 
separate humidity measurements at each intake, use a flow-weighted 
average humidity for NOX corrections. If individual flows of 
each intake are not measured, use good engineering judgment to estimate 
a flow-weighted average humidity.
    (3) Temperature. Good engineering judgment may require that you 
shield the temperature sensors or move them upstream of an elbow in the 
laboratory intake system to prevent measurement errors due to radiant 
heating from hot engine surfaces or in-use intake system components. You 
must limit the distance between the temperature sensor and the entrance 
to the furthest upstream engine or in-use intake system component to no 
more than 12 times the outer hydraulic diameter of the entrance to the 
furthest upstream engine or in-use intake system component. However, you 
may exceed this limit if you use good engineering judgment to show that 
the temperature at the furthest upstream engine or in-use intake system 
component meets the specification in paragraph (c) of this section. For 
engines with multiple intakes, use a flow-weighted average value to 
verify compliance with the specification in paragraph (c) of this 
section. If individual flows of each intake are not measured, you may 
use good engineering judgment to estimate a flow-weighted average 
temperature. You may also verify that each individual intake complies 
with the specification in paragraph (c) of this section.
    (c) Maintain the temperature of intake air to (25 5) [deg]C, except as follows:
    (1) Follow the standard-setting part if it specifies different 
temperatures.
    (2) For engines above 560 kW, you may use 35 [deg]C as the upper 
bound of the tolerance. However, your system must be capable of 
controlling the temperature to the 25 [deg]C setpoint for any

[[Page 67]]

steady-state operation at 30% of maximum engine power.
    (3) You may ask us to allow you to apply a different setpoint for 
intake air temperature if it is necessary to remain consistent with the 
provisions of Sec.  1065.10(c)(1) for testing during which ambient 
temperature will be outside this range.
    (d) Use an intake-air restriction that represents production 
engines. Make sure the intake-air restriction is between the 
manufacturer's specified maximum for a clean filter and the 
manufacturer's specified maximum allowed. Measure the static 
differential pressure of the restriction at the location and at the 
speed and torque set points specified by the manufacturer. If the 
manufacturer does not specify a location, measure this pressure upstream 
of any turbocharger or exhaust gas recirculation system connection to 
the intake air system. If the manufacturer does not specify speed and 
torque points, measure this pressure while the engine outputs maximum 
power. As the manufacturer, you are liable for emission compliance for 
all values up to the maximum restriction you specify for a particular 
engine.
    (e) This paragraph (e) includes provisions for simulating charge-air 
cooling in the laboratory. This approach is described in paragraph 
(e)(1) of this section. Limits on using this approach are described in 
paragraphs (e)(2) and (3) of this section.
    (1) Use a charge-air cooling system with a total intake-air capacity 
that represents production engines' in-use installation. Design any 
laboratory charge-air cooling system to minimize accumulation of 
condensate. Drain any accumulated condensate. Before starting a duty 
cycle (or preconditioning for a duty cycle), completely close all drains 
that would normally be closed during in-use operation. Keep those drains 
closed during the emission test. Maintain coolant conditions as follows:
    (i) Maintain a coolant temperature of at least 20 [deg]C at the 
inlet to the charge-air cooler throughout testing. We recommend 
maintaining a coolant temperature of 25 5 [deg]C 
at the inlet of the charge-air cooler.
    (ii) At the engine conditions specified by the manufacturer, set the 
coolant flow rate to achieve an air temperature within 5 [deg]C of the value specified by the manufacturer 
after the charge-air cooler's outlet. Measure the air-outlet temperature 
at the location specified by the manufacturer. Use this coolant flow 
rate set point throughout testing. If the engine manufacturer does not 
specify engine conditions or the corresponding charge-air cooler air 
outlet temperature, set the coolant flow rate at maximum engine power to 
achieve a charge-air cooler air outlet temperature that represents in-
use operation.
    (iii) If the engine manufacturer specifies pressure-drop limits 
across the charge-air cooling system, ensure that the pressure drop 
across the charge-air cooling system at engine conditions specified by 
the manufacturer is within the manufacturer's specified limit(s). 
Measure the pressure drop at the manufacturer's specified locations.
    (2) Using a constant flow rate as described in paragraph (e)(1) of 
this section may result in unrepresentative overcooling of the intake 
air. The provisions of this paragraph (e)(2) apply instead of the 
provisions of Sec.  1065.10(c)(1) for this simulation. Our allowance to 
cool intake air as specified in this paragraph (e) does not affect your 
liability for field testing or for laboratory testing that is done in a 
way that better represents in-use operation. Where we determine that 
this allowance adversely affects your ability to demonstrate that your 
engines would comply with emission standards under in-use conditions, we 
may require you to use more sophisticated setpoints and controls of 
charge-air pressure drop, coolant temperature, and flow rate to achieve 
more representative results.
    (3) This approach does not apply for field testing. You may not 
correct measured emission levels from field testing to account for any 
differences caused by the simulated cooling in the laboratory.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37293, June 30, 2008; 
73 FR 59321, Oct. 8, 2008; 75 FR 23029, Apr. 30, 2010; 76 FR 57440, 
Sept. 15, 2011]



Sec.  1065.127  Exhaust gas recirculation.

    Use the exhaust gas recirculation (EGR) system installed with the 
engine

[[Page 68]]

or one that represents a typical in-use configuration. This includes any 
applicable EGR cooling devices.



Sec.  1065.130  Engine exhaust.

    (a) General. Use the exhaust system installed with the engine or one 
that represents a typical in-use configuration. This includes any 
applicable aftertreatment devices. We refer to exhaust piping as an 
exhaust stack; this is equivalent to a tailpipe for vehicle 
configurations.
    (b) Aftertreatment configuration. If you do not use the exhaust 
system installed with the engine, configure any aftertreatment devices 
as follows:
    (1) Position any aftertreatment device so its distance from the 
nearest exhaust manifold flange or turbocharger outlet is within the 
range specified by the engine manufacturer in the application for 
certification. If this distance is not specified, position 
aftertreatment devices to represent typical in-use vehicle 
configurations.
    (2) You may use exhaust tubing that is not from the in-use exhaust 
system upstream of any aftertreatment device that is of diameter(s) 
typical of in-use configurations. If you use exhaust tubing that is not 
from the in-use exhaust system upstream of any aftertreatment device, 
position each aftertreatment device according to paragraph (b)(1) of 
this section.
    (c) Sampling system connections. Connect an engine's exhaust system 
to any raw sampling location or dilution stage, as follows:
    (1) Minimize laboratory exhaust tubing lengths and use a total 
length of laboratory tubing of no more than 10 m or 50 outside 
diameters, whichever is greater. The start of laboratory exhaust tubing 
should be specified as the exit of the exhaust manifold, turbocharger 
outlet, last aftertreatment device, or the in-use exhaust system, 
whichever is furthest downstream. The end of laboratory exhaust tubing 
should be specified as the sample point, or first point of dilution. If 
laboratory exhaust tubing consists of several different outside tubing 
diameters, count the number of diameters of length of each individual 
diameter, then sum all the diameters to determine the total length of 
exhaust tubing in diameters. Use the mean outside diameter of any 
converging or diverging sections of tubing. Use outside hydraulic 
diameters of any noncircular sections. For multiple stack configurations 
where all the exhaust stacks are combined, the start of the laboratory 
exhaust tubing may be taken at the last joint of where all the stacks 
are combined.
    (2) You may install short sections of flexible laboratory exhaust 
tubing at any location in the engine or laboratory exhaust systems. You 
may use up to a combined total of 2 m or 10 outside diameters of 
flexible exhaust tubing.
    (3) Insulate any laboratory exhaust tubing downstream of the first 
25 outside diameters of length.
    (4) Use laboratory exhaust tubing materials that are smooth-walled, 
electrically conductive, and not reactive with exhaust constituents. 
Stainless steel is an acceptable material.
    (5) We recommend that you use laboratory exhaust tubing that has 
either a wall thickness of less than 2 mm or is air gap-insulated to 
minimize temperature differences between the wall and the exhaust.
    (6) We recommend that you connect multiple exhaust stacks from a 
single engine into one stack upstream of any emission sampling. For raw 
or dilute partial-flow emission sampling, to ensure mixing of the 
multiple exhaust streams before emission sampling, we recommend a 
minimum Reynolds number, Re #, of 4000 for the combined 
exhaust stream, where Re # is based on the inside diameter of 
the combined flow at the first sampling point. You may configure the 
exhaust system with turbulence generators, such as orifice plates or 
fins, to achieve good mixing; inclusion of turbulence generators may be 
required for Re # less than 4000 to ensure good mixing. Re 
# is defined in Sec.  1065.640. For dilute full-flow (CVS) 
emission sampling, you may configure the exhaust system without regard 
to mixing in the laboratory section of the raw exhaust. For example you 
may size the laboratory section to reduce its pressure drop even if the 
Re #, in the laboratory section of the raw exhaust is less 
than 4000.
    (d) In-line instruments. You may insert instruments into the 
laboratory exhaust tubing, such as an in-line

[[Page 69]]

smoke meter. If you do this, you may leave a length of up to 5 outside 
diameters of laboratory exhaust tubing uninsulated on each side of each 
instrument, but you must leave a length of no more than 25 outside 
diameters of laboratory exhaust tubing uninsulated in total, including 
any lengths adjacent to in-line instruments.
    (e) Leaks. Minimize leaks sufficiently to ensure your ability to 
demonstrate compliance with the applicable standards in this chapter. We 
recommend performing carbon balance error verification as described in 
Sec.  1065.543 to verify exhaust system integrity.
    (f) Grounding. Electrically ground the entire exhaust system.
    (g) Forced cooldown. You may install a forced cooldown system for an 
exhaust aftertreatment device according to Sec.  1065.530(a)(1)(i).
    (h) Exhaust restriction. As the manufacturer, you are liable for 
emission compliance for all values up to the maximum restriction(s) you 
specify for a particular engine. Measure and set exhaust restriction(s) 
at the location(s) and at the engine speed and torque values specified 
by the manufacturer. Also, for variable-restriction aftertreatment 
devices, measure and set exhaust restriction(s) at the aftertreatment 
condition (degreening/aging and regeneration/loading level) specified by 
the manufacturer. If the manufacturer does not specify a location, 
measure this pressure downstream of any turbocharger. If the 
manufacturer does not specify speed and torque points, measure pressure 
while the engine produces maximum power. Use an exhaust-restriction 
setpoint that represents a typical in-use value, if available. If a 
typical in-use value for exhaust restriction is not available, set the 
exhaust restriction at (80 to 100)% of the maximum exhaust restriction 
specified by the manufacturer, or if the maximum is 5 kPa or less, the 
set point must be no less than 1.0 kPa from the maximum. For example, if 
the maximum back pressure is 4.5 kPa, do not use an exhaust restriction 
set point that is less than 3.5 kPa.
    (i) Open crankcase emissions. If the standard-setting part requires 
measuring open crankcase emissions, you may either measure open 
crankcase emissions separately using a method that we approve in 
advance, or route open crankcase emissions directly into the exhaust 
system for emission measurement. If the engine is not already configured 
to route open crankcase emissions for emission measurement, route open 
crankcase emissions as follows:
    (1) Use laboratory tubing materials that are smooth-walled, 
electrically conductive, and not reactive with crankcase emissions. 
Stainless steel is an acceptable material. Minimize tube lengths. We 
also recommend using heated or thin-walled or air gap-insulated tubing 
to minimize temperature differences between the wall and the crankcase 
emission constituents.
    (2) Minimize the number of bends in the laboratory crankcase tubing 
and maximize the radius of any unavoidable bend.
    (3) Use laboratory crankcase exhaust tubing that meets the engine 
manufacturer's specifications for crankcase back pressure.
    (4) Connect the crankcase exhaust tubing into the raw exhaust 
downstream of any aftertreatment system, downstream of any installed 
exhaust restriction, and sufficiently upstream of any sample probes to 
ensure complete mixing with the engine's exhaust before sampling. Extend 
the crankcase exhaust tube into the free stream of exhaust to avoid 
boundary-layer effects and to promote mixing. You may orient the 
crankcase exhaust tube's outlet in any direction relative to the raw 
exhaust flow.

[73 FR 37293, June 30, 2008, as amended at 79 FR 23754, Apr. 28, 2014; 
86 FR 34534, June 29, 2021]



Sec.  1065.140  Dilution for gaseous and PM constituents.

    (a) General. You may dilute exhaust with ambient air, purified air, 
or nitrogen. References in this part to ``dilution air'' may include any 
of these. For gaseous emission measurement, the dilution air must be at 
least 15 [deg]C. Note that the composition of the dilution air affects 
some gaseous emission measurement instruments' response to emissions. We 
recommend diluting exhaust at a location as close as possible

[[Page 70]]

to the location where ambient air dilution would occur in use. Dilution 
may occur in a single stage or in multiple stages. For dilution in 
multiple stages, the first stage is considered primary dilution and 
later stages are considered secondary dilution.
    (b) Dilution-air conditions and background concentrations. Before 
dilution air is mixed with exhaust, you may precondition it by 
increasing or decreasing its temperature or humidity. You may also 
remove constituents to reduce their background concentrations. The 
following provisions apply to removing constituents or accounting for 
background concentrations:
    (1) You may measure constituent concentrations in the dilution air 
and compensate for background effects on test results. See Sec.  
1065.650 for calculations that compensate for background concentrations 
(40 CFR 1066.610 for vehicle testing).
    (2) Measure these background concentrations the same way you measure 
diluted exhaust constituents, or measure them in a way that does not 
affect your ability to demonstrate compliance with the applicable 
standards in this chapter. For example, you may use the following 
simplifications for background sampling:
    (i) You may disregard any proportional sampling requirements.
    (ii) You may use unheated gaseous sampling systems.
    (iii) You may use unheated PM sampling systems.
    (iv) You may use continuous sampling if you use batch sampling for 
diluted emissions.
    (v) You may use batch sampling if you use continuous sampling for 
diluted emissions.
    (3) For removing background PM, we recommend that you filter all 
dilution air, including primary full-flow dilution air, with high-
efficiency particulate air (HEPA) filters that have an initial minimum 
collection efficiency specification of 99.97% (see Sec.  1065.1001 for 
procedures related to HEPA-filtration efficiencies). Ensure that HEPA 
filters are installed properly so that background PM does not leak past 
the HEPA filters. If you choose to correct for background PM without 
using HEPA filtration, demonstrate that the background PM in the 
dilution air contributes less than 50% to the net PM collected on the 
sample filter. You may correct net PM without restriction if you use 
HEPA filtration.
    (c) Full-flow dilution; constant-volume sampling (CVS). You may 
dilute the full flow of raw exhaust in a dilution tunnel that maintains 
a nominally constant volume flow rate, molar flow rate or mass flow rate 
of diluted exhaust, as follows:
    (1) Construction. Use a tunnel with inside surfaces of 300 series 
stainless steel. Electrically ground the entire dilution tunnel. We 
recommend a thin-walled and insulated dilution tunnel to minimize 
temperature differences between the wall and the exhaust gases. You may 
not use any flexible tubing in the dilution tunnel upstream of the PM 
sample probe. You may use nonconductive flexible tubing downstream of 
the PM sample probe and upstream of the CVS flow meter; use good 
engineering judgment to select a tubing material that is not prone to 
leaks, and configure the tubing to ensure smooth flow at the CVS flow 
meter.
    (2) Pressure control. Maintain static pressure at the location where 
raw exhaust is introduced into the tunnel within 1.2 kPa of atmospheric pressure. You may use a booster 
blower to control this pressure. If you test using more careful pressure 
control and you show by engineering analysis or by test data that you 
require this level of control to demonstrate compliance at the 
applicable standards in this chapter, we will maintain the same level of 
static pressure control when we test.
    (3) Mixing. Introduce raw exhaust into the tunnel by directing it 
downstream along the centerline of the tunnel. If you dilute directly 
from the exhaust stack, the end of the exhaust stack is considered to be 
the start of the dilution tunnel. You may introduce a fraction of 
dilution air radially from the tunnel's inner surface to minimize 
exhaust interaction with the tunnel walls. You may configure the system 
with turbulence generators such as orifice plates or fins to achieve 
good mixing. We recommend a minimum Reynolds number, Re #, of 
4000 for the diluted exhaust stream, where Re # is

[[Page 71]]

based on the inside diameter of the dilution tunnel. Re # is 
defined in Sec.  1065.640.
    (4) Flow measurement preconditioning. You may condition the diluted 
exhaust before measuring its flow rate, as long as this conditioning 
takes place downstream of any heated HC or PM sample probes, as follows:
    (i) You may use flow straighteners, pulsation dampeners, or both of 
these.
    (ii) You may use a filter.
    (iii) You may use a heat exchanger to control the temperature 
upstream of any flow meter, but you must take steps to prevent aqueous 
condensation as described in paragraph (c)(6) of this section.
    (5) Flow measurement. Section 1065.240 describes measurement 
instruments for diluted exhaust flow.
    (6) Aqueous condensation. You must address aqueous condensation in 
the CVS as described in this paragraph (c)(6). You may meet these 
requirements by preventing or limiting aqueous condensation in the CVS 
from the exhaust inlet to the last emission sample probe. See paragraph 
(c)(6)(2)(B) of this section for provisions related to the CVS between 
the last emission sample probe and the CVS flow meter. You may heat and/
or insulate the dilution tunnel walls, as well as the bulk stream tubing 
downstream of the tunnel to prevent or limit aqueous condensation. Where 
we allow aqueous condensation to occur, use good engineering judgment to 
ensure that the condensation does not affect your ability to demonstrate 
that your engines comply with the applicable standards in this chapter 
(see Sec.  1065.10(a)).
    (i) Preventing aqueous condensation. To prevent condensation, you 
must keep the temperature of internal surfaces, excluding any sample 
probes, above the dewpoint of the dilute exhaust passing through the CVS 
tunnel. Use good engineering judgment to monitor temperatures in the 
CVS. For the purposes of this paragraph (c)(6), assume that aqueous 
condensation is pure water condensate only, even though the definition 
of ``aqueous condensation'' in Sec.  1065.1001 includes condensation of 
any constituents that contain water. No specific verification check is 
required under this paragraph (c)(6)(i), but we may ask you to show how 
you comply with this requirement. You may use engineering analysis, CVS 
tunnel design, alarm systems, measurements of wall temperatures, and 
calculation of water dewpoint to demonstrate compliance with this 
requirement. For optional CVS heat exchangers, you may use the lowest 
water temperature at the inlet(s) and outlet(s) to determine the minimum 
internal surface temperature.
    (ii) Limiting aqueous condensation. This paragraph (c)(6)(ii) 
specifies limits of allowable condensation and requires you to verify 
that the amount of condensation that occurs during each test interval 
does not exceed the specified limits.
    (A) Use chemical balance equations in Sec.  1065.655 to calculate 
the mole fraction of water in the dilute exhaust continuously during 
testing. Alternatively, you may continuously measure the mole fraction 
of water in the dilute exhaust prior to any condensation during testing. 
Use good engineering judgment to select, calibrate and verify water 
analyzers/detectors. The linearity verification requirements of Sec.  
1065.307 do not apply to water analyzers/detectors used to correct for 
the water content in exhaust samples.
    (B) Use good engineering judgment to select and monitor locations on 
the CVS tunnel walls prior to the last emission sample probe. If you are 
also verifying limited condensation from the last emission sample probe 
to the CVS flow meter, use good engineering judgment to select and 
monitor locations on the CVS tunnel walls, optional CVS heat exchanger, 
and CVS flow meter. For optional CVS heat exchangers, you may use the 
lowest water temperature at the inlet(s) and outlet(s) to determine the 
minimum internal surface temperature. Identify the minimum surface 
temperature on a continuous basis.
    (C) Identify the maximum potential mole fraction of dilute exhaust 
lost on a continuous basis during the entire test interval. This value 
must be less than or equal to 0.02. Calculate on a continuous basis the 
mole fraction of water that would be in equilibrium with liquid water at 
the measured minimum surface temperature. Subtract

[[Page 72]]

this mole fraction from the mole fraction of water that would be in the 
exhaust without condensation (either measured or from the chemical 
balance), and set any negative values to zero. This difference is the 
potential mole fraction of the dilute exhaust that would be lost due to 
water condensation on a continuous basis.
    (D) Integrate the product of the molar flow rate of the dilute 
exhaust and the potential mole fraction of dilute exhaust lost, and 
divide by the totalized dilute exhaust molar flow over the test 
interval. This is the potential mole fraction of the dilute exhaust that 
would be lost due to water condensation over the entire test interval. 
Note that this assumes no re-evaporation. This value must be less than 
or equal to 0.005.
    (7) Flow compensation. Maintain nominally constant molar, volumetric 
or mass flow of diluted exhaust. You may maintain nominally constant 
flow by either maintaining the temperature and pressure at the flow 
meter or by directly controlling the flow of diluted exhaust. You may 
also directly control the flow of proportional samplers to maintain 
proportional sampling. For an individual test, verify proportional 
sampling as described in Sec.  1065.545.
    (d) Partial-flow dilution (PFD). You may dilute a partial flow of 
raw or previously diluted exhaust before measuring emissions. Section 
1065.240 describes PFD-related flow measurement instruments. PFD may 
consist of constant or varying dilution ratios as described in 
paragraphs (d)(2) and (3) of this section. An example of a constant 
dilution ratio PFD is a ``secondary dilution PM'' measurement system.
    (1) Applicability. (i) You may use PFD to extract a proportional raw 
exhaust sample for any batch or continuous PM emission sampling over any 
transient duty cycle, any steady-state duty cycle, or any ramped-modal 
cycle.
    (ii) You may use PFD to extract a proportional raw exhaust sample 
for any batch or continuous gaseous emission sampling over any transient 
duty cycle, any steady-state duty cycle, or any ramped-modal cycle.
    (iii) You may use PFD to extract a proportional raw exhaust sample 
for any batch or continuous field-testing.
    (iv) You may use PFD to extract a proportional diluted exhaust 
sample from a CVS for any batch or continuous emission sampling.
    (v) You may use PFD to extract a constant raw or diluted exhaust 
sample for any continuous emission sampling.
    (vi) You may use PFD to extract a constant raw or diluted exhaust 
sample for any steady-state emission sampling.
    (2) Constant dilution-ratio PFD. Do one of the following for 
constant dilution-ratio PFD:
    (i) Dilute an already proportional flow. For example, you may do 
this as a way of performing secondary dilution from a CVS tunnel to 
achieve overall dilution ratio for PM sampling.
    (ii) Continuously measure constituent concentrations. For example, 
you might dilute to precondition a sample of raw exhaust to control its 
temperature, humidity, or constituent concentrations upstream of 
continuous analyzers. In this case, you must take into account the 
dilution ratio before multiplying the continuous concentration by the 
sampled exhaust flow rate.
    (iii) Extract a proportional sample from a separate constant 
dilution ratio PFD system. For example, you might use a variable-flow 
pump to proportionally fill a gaseous storage medium such as a bag from 
a PFD system. In this case, the proportional sampling must meet the same 
specifications as varying dilution ratio PFD in paragraph (d)(3) of this 
section.
    (iv) For each mode of a discrete-mode test (such as a locomotive 
notch setting or a specific setting for speed and torque), use a 
constant dilution ratio for any PM sampling. You must change the overall 
PM sampling system dilution ratio between modes so that the dilution 
ratio on the mode with the highest exhaust flow rate meets Sec.  
1065.140(e)(2) and the dilution ratios on all other modes is higher than 
this (minimum) dilution ratio by the ratio of the maximum exhaust flow 
rate to the exhaust flow rate of the corresponding other mode. This is 
the same dilution ratio requirement for RMC or field transient testing. 
You must account for this change in dilution ratio in your emission 
calculations.

[[Page 73]]

    (3) Varying dilution-ratio PFD. All the following provisions apply 
for varying dilution-ratio PFD:
    (i) Use a control system with sensors and actuators that can 
maintain proportional sampling over intervals as short as 200 ms (i.e., 
5 Hz control).
    (ii) For control input, you may use any sensor output from one or 
more measurements; for example, intake-air flow, fuel flow, exhaust 
flow, engine speed, and intake manifold temperature and pressure.
    (iii) Account for any emission transit time in the PFD system, as 
necessary.
    (iv) You may use preprogrammed data if they have been determined for 
the specific test site, duty cycle, and test engine from which you 
dilute emissions.
    (v) We recommend that you run practice cycles to meet the 
verification criteria in Sec.  1065.545. Note that you must verify every 
emission test by meeting the verification criteria with the data from 
that specific test. Data from previously verified practice cycles or 
other tests may not be used to verify a different emission test.
    (vi) You may not use a PFD system that requires preparatory tuning 
or calibration with a CVS or with the emission results from a CVS. 
Rather, you must be able to independently calibrate the PFD.
    (e) Dilution air temperature, dilution ratio, residence time, and 
temperature control of PM samples. Dilute PM samples at least once 
upstream of transfer lines. You may dilute PM samples upstream of a 
transfer line using full-flow dilution, or partial-flow dilution 
immediately downstream of a PM probe. In the case of partial-flow 
dilution, you may have up to 26 cm of insulated length between the end 
of the probe and the dilution stage, but we recommend that the length be 
as short as practical. The intent of these specifications is to minimize 
heat transfer to or from the emission sample before the final stage of 
dilution, other than the heat you may need to add to prevent aqueous 
condensation. This is accomplished by initially cooling the sample 
through dilution. Configure dilution systems as follows:
    (1) Set the dilution air temperature to (25 5) 
[deg]C. Use good engineering judgment to select a location to measure 
this temperature that is as close as practical upstream of the point 
where dilution air mixes with raw exhaust.
    (2) For any PM dilution system (i.e., CVS or PFD), add dilution air 
to the raw exhaust such that the minimum overall ratio of diluted 
exhaust to raw exhaust is within the range of (5:1 to 7:1) and is at 
least 2:1 for any primary dilution stage. Base this minimum value on the 
maximum engine exhaust flow rate during a given duty cycle for discrete-
mode testing and on the maximum engine exhaust flow rate during a given 
test interval for other testing. Either measure the maximum exhaust flow 
during a practice run of the test interval or estimate it based on good 
engineering judgment (for example, you might rely on manufacturer-
published literature).
    (3) Configure any PM dilution system to have an overall residence 
time of (1.0 to 5.5) s, as measured from the location of initial 
dilution air introduction to the location where PM is collected on the 
sample media. Also configure the system to have a residence time of at 
least 0.50 s, as measured from the location of final dilution air 
introduction to the location where PM is collected on the sample media. 
When determining residence times within sampling system volumes, use an 
assumed flow temperature of 25 [deg]C and pressure of 101.325 kPa.
    (4) Control sample temperature to a (47 5) 
[deg]C tolerance, as measured anywhere within 20 cm upstream or 
downstream of the PM storage media (such as a filter). You may instead 
measure sample temperature up to 30 cm upstream of the filter or other 
PM storage media if it is housed within a chamber with temperature 
controlled to stay within the specified temperature range. Measure 
sample temperature with a bare-wire junction thermocouple with wires 
that are (0.500 0.025) mm diameter, or with 
another suitable instrument that has equivalent performance.

[79 FR 23754, Apr. 28, 2014, as amended at 81 FR 74162, Oct. 25, 2016; 
86 FR 34534, June 29, 2021; 88 FR 4670, Jan. 24, 2023]

[[Page 74]]



Sec.  1065.145  Gaseous and PM probes, transfer lines, and 
sampling system components.

    (a) Continuous and batch sampling. Determine the total mass of each 
constituent with continuous or batch sampling. Both types of sampling 
systems have probes, transfer lines, and other sampling system 
components that are described in this section.
    (b) Options for engines with multiple exhaust stacks. Measure 
emissions from a test engine as described in this paragraph (b) if it 
has multiple exhaust stacks. You may choose to use different measurement 
procedures for different pollutants under this paragraph (b) for a given 
test. For purposes of this part 1065, the test engine includes all the 
devices related to converting the chemical energy in the fuel to the 
engine's mechanical output energy. This may or may not involve vehicle- 
or equipment-based devices. For example, all of an engine's cylinders 
are considered to be part of the test engine even if the exhaust is 
divided into separate exhaust stacks. As another example, all the 
cylinders of a diesel-electric locomotive are considered to be part of 
the test engine even if they transmit power through separate output 
shafts, such as might occur with multiple engine-generator sets working 
in tandem. Use one of the following procedures to measure emissions with 
multiple exhaust stacks:
    (1) Route the exhaust flow from the multiple stacks into a single 
flow as described in Sec.  1065.130(c)(6). Sample and measure emissions 
after the exhaust streams are mixed. Calculate the emissions as a single 
sample from the entire engine. We recommend this as the preferred 
option, since it requires only a single measurement and calculation of 
the exhaust molar flow for the entire engine.
    (2) Sample and measure emissions from each stack and calculate 
emissions separately for each stack. Add the mass (or mass rate) 
emissions from each stack to calculate the emissions from the entire 
engine. Testing under this paragraph (b)(2) requires measuring or 
calculating the exhaust molar flow for each stack separately. If the 
exhaust molar flow in each stack cannot be calculated from intake air 
flow(s), fuel flow(s), and measured gaseous emissions, and it is 
impractical to measure the exhaust molar flows directly, you may 
alternatively proportion the engine's calculated total exhaust molar 
flow rate (where the flow is calculated using intake air mass flow(s), 
fuel mass flow(s), and emissions concentrations) based on exhaust molar 
flow measurements in each stack using a less accurate, non-traceable 
method. For example, you may use a total pressure probe and static 
pressure measurement in each stack.
    (3) Sample and measure emissions from one stack and repeat the duty 
cycle as needed to collect emissions from each stack separately. 
Calculate the emissions from each stack and add the separate 
measurements to calculate the mass (or mass rate) emissions from the 
entire engine. Testing under this paragraph (b)(3) requires measuring or 
calculating the exhaust molar flow for each stack separately. You may 
alternatively proportion the engine's calculated total exhaust molar 
flow rate based on calculation and measurement limitations as described 
in paragraph (b)(2) of this section. Use the average of the engine's 
total power or work values from the multiple test runs to calculate 
brake-specific emissions. Divide the total mass (or mass rate) of each 
emission by the average power (or work). You may alternatively use the 
engine power or work associated with the corresponding stack during each 
test run if these values can be determined for each stack separately.
    (4) Sample and measure emissions from each stack separately and 
calculate emissions for the entire engine based on the stack with the 
highest concentration. Testing under this paragraph (b)(4) requires only 
a single exhaust flow measurement or calculation for the entire engine. 
You may determine which stack has the highest concentration by 
performing multiple test runs, reviewing the results of earlier tests, 
or using good engineering judgment. Note that the highest concentration 
of different pollutants may occur in different stacks. Note also that 
the stack with the highest concentration of a pollutant during a test 
interval for field testing may be a different stack

[[Page 75]]

than the one you identified based on average concentrations over a duty 
cycle.
    (5) Sample emissions from each stack separately and combine the wet 
sample streams from each stack proportionally to the exhaust molar flows 
in each stack. Measure the emission concentrations and calculate the 
emissions for the entire engine based on these weighted concentrations. 
Testing under this paragraph (b)(5) requires measuring or calculating 
the exhaust molar flow for each stack separately during the test run to 
proportion the sample streams from each stack. If it is impractical to 
measure the exhaust molar flows directly, you may alternatively 
proportion the wet sample streams based on less accurate, non-traceable 
flow methods. For example, you may use a total pressure probe and static 
pressure measurement in each stack. The following restrictions apply for 
testing under this paragraph (b)(5):
    (i) You must use an accurate, traceable measurement or calculation 
of the engine's total exhaust molar flow rate for calculating the mass 
of emissions from the entire engine.
    (ii) You may dry the single, combined, proportional sample stream; 
you may not dry the sample streams from each stack separately.
    (iii) You must measure and proportion the sample flows from each 
stack with active flow controls. For PM sampling, you must measure and 
proportion the diluted sample flows from each stack with active flow 
controls that use only smooth walls with no sudden change in cross-
sectional area. For example, you may control the dilute exhaust PM 
sample flows using electrically conductive vinyl tubing and a control 
device that pinches the tube over a long enough transition length so no 
flow separation occurs.
    (iv) For PM sampling, the transfer lines from each stack must be 
joined so the angle of the joining flows is 12.5[deg] or less. Note that 
the exhaust manifold must meet the same specifications as the transfer 
line according to paragraph (d) of this section.
    (6) Sample emissions from each stack separately and combine the wet 
sample streams from each stack equally. Measure the emission 
concentrations and calculate the emissions for the entire engine based 
on these measured concentrations. Testing under this paragraph (b)(6) 
assumes that the raw-exhaust and sample flows are the same for each 
stack. The following restrictions apply for testing under this paragraph 
(b)(6):
    (i) You must measure and demonstrate that the sample flow from each 
stack is within 5% of the value from the stack with the highest sample 
flow. You may alternatively ensure that the stacks have equal flow rates 
without measuring sample flows by designing a passive sampling system 
that meets the following requirements:
    (A) The probes and transfer line branches must be symmetrical, have 
equal lengths and diameters, have the same number of bends, and have no 
filters.
    (B) If probes are designed such that they are sensitive to stack 
velocity, the stack velocity must be similar at each probe. For example, 
a static pressure probe used for gaseous sampling is not sensitive to 
stack velocity.
    (C) The stack static pressure must be the same at each probe. You 
can meet this requirement by placing probes at the end of stacks that 
are vented to atmosphere.
    (D) For PM sampling, the transfer lines from each stack must be 
joined so the angle of the joining flows is 12.5[deg] or less. Note that 
the exhaust manifold must meet the same specifications as the transfer 
line according to paragraph (d) of this section.
    (ii) You may use the procedure in this paragraph (b)(6) only if you 
perform an analysis showing that the resulting error due to imbalanced 
stack flows and concentrations is either at or below 2%. You may 
alternatively show that the resulting error does not impact your ability 
to demonstrate compliance with applicable standards. For example, you 
may use less accurate, non-traceable measurements of emission 
concentrations and molar flow in each stack and demonstrate that the 
imbalances in flows and concentrations cause 2% or less error.
    (iii) For a two-stack engine, you may use the procedure in this 
paragraph (b)(6) only if you can show that the stack with the higher 
flow has the

[[Page 76]]

lower average concentration for each pollutant over the duty cycle.
    (iv) You must use an accurate, traceable measurement or calculation 
of the engine's total exhaust molar flow rate for calculating the mass 
of emissions from the entire engine.
    (v) You may dry the single, equally combined, sample stream; you may 
not dry the sample streams from each stack separately.
    (vi) You may determine your exhaust flow rates with a chemical 
balance of exhaust gas concentrations and either intake air flow or fuel 
flow.
    (c) Gaseous and PM sample probes. A probe is the first fitting in a 
sampling system. It protrudes into a raw or diluted exhaust stream to 
extract a sample, such that its inside and outside surfaces are in 
contact with the exhaust. A sample is transported out of a probe into a 
transfer line, as described in paragraph (d) of this section. The 
following provisions apply to sample probes:
    (1) Probe design and construction. Use sample probes with inside 
surfaces of 300 series stainless steel or, for raw exhaust sampling, use 
any nonreactive material capable of withstanding raw exhaust 
temperatures. Locate sample probes where constituents are mixed to their 
mean sample concentration. Take into account the mixing of any crankcase 
emissions that may be routed into the raw exhaust. Locate each probe to 
minimize interference with the flow to other probes. We recommend that 
all probes remain free from influences of boundary layers, wakes, and 
eddies--especially near the outlet of a raw-exhaust stack where 
unintended dilution might occur. Make sure that purging or back-flushing 
of a probe does not influence another probe during testing. You may use 
a single probe to extract a sample of more than one constituent as long 
as the probe meets all the specifications for each constituent.
    (2) Gaseous sample probes. Use either single-port or multi-port 
probes for sampling gaseous emissions. You may orient these probes in 
any direction relative to the raw or diluted exhaust flow. For some 
probes, you must control sample temperatures, as follows:
    (i) For probes that extract NOX from diluted exhaust, 
control the probe's wall temperature to prevent aqueous condensation.
    (ii) For probes that extract hydrocarbons for THC or NMHC analysis 
from the diluted exhaust of compression-ignition engines, two-stroke 
spark-ignition engines, or four-stroke spark-ignition engines at or 
below 19 kW, we recommend heating the probe to minimize hydrocarbon 
contamination consistent with good engineering judgment. If you 
routinely fail the contamination check in the 1065.520 pretest check, we 
recommend heating the probe section to approximately 190 [deg]C to 
minimize contamination.
    (3) PM sample probes. Use PM probes with a single opening at the 
end. Orient PM probes to face directly upstream. If you shield a PM 
probe's opening with a PM pre-classifier such as a hat, you may not use 
the preclassifier we specify in paragraph (f)(1) of this section. We 
recommend sizing the inside diameter of PM probes to approximate 
isokinetic sampling at the expected mean flow rate.
    (d) Transfer lines. You may use transfer lines to transport an 
extracted sample from a probe to an analyzer, storage medium, or 
dilution system, noting certain restrictions for PM sampling in Sec.  
1065.140(e). Minimize the length of all transfer lines by locating 
analyzers, storage media, and dilution systems as close to probes as 
practical. We recommend that you minimize the number of bends in 
transfer lines and that you maximize the radius of any unavoidable bend. 
Avoid using 90[deg] elbows, tees, and cross-fittings in transfer lines. 
Where such connections and fittings are necessary, take steps, using 
good engineering judgment, to ensure that you meet the temperature 
tolerances in this paragraph (d). This may involve measuring temperature 
at various locations within transfer lines and fittings. You may use a 
single transfer line to transport a sample of more than one constituent, 
as long as the transfer line meets all the specifications for each 
constituent. The following construction and temperature tolerances apply 
to transfer lines:
    (1) Gaseous samples. Use transfer lines with inside surfaces of 300 
series stainless steel, PTFE, Viton \TM\, or any other material that you 
demonstrate

[[Page 77]]

has better properties for emission sampling. For raw exhaust sampling, 
use a non-reactive material capable of withstanding raw exhaust 
temperatures. You may use in-line filters if they do not react with 
exhaust constituents and if the filter and its housing meet the same 
temperature requirements as the transfer lines, as follows:
    (i) For NOX transfer lines upstream of either an 
NO2-to-NO converter that meets the specifications of Sec.  
1065.378 or a chiller that meets the specifications of Sec.  1065.376, 
maintain a sample temperature that prevents aqueous condensation.
    (ii) For THC transfer lines for testing compression-ignition 
engines, two-stroke spark-ignition engines, or four-stroke spark-
ignition engines at or below 19 kW, maintain a wall temperature 
tolerance throughout the entire line of (191 11) 
[deg]C. If you sample from raw exhaust, you may connect an unheated, 
insulated transfer line directly to a probe. Design the length and 
insulation of the transfer line to cool the highest expected raw exhaust 
temperature to no lower than 191 [deg]C, as measured at the transfer 
line's outlet. For dilute sampling, you may use a transition zone 
between the probe and transfer line of up to 92 cm to allow your wall 
temperature to transition to (191 11) [deg]C.
    (2) PM samples. We recommend heated transfer lines or a heated 
enclosure to minimize temperature differences between transfer lines and 
exhaust constituents. Use transfer lines that are inert with respect to 
PM and are electrically conductive on the inside surfaces. We recommend 
using PM transfer lines made of 300 series stainless steel. Electrically 
ground the inside surface of PM transfer lines.
    (e) Optional sample-conditioning components for gaseous sampling. 
You may use the following sample-conditioning components to prepare 
gaseous samples for analysis, as long as you do not install or use them 
in a way that adversely affects your ability to show that your engines 
comply with all applicable gaseous emission standards.
    (1) NO2-to-NO converter. You may use an NO2-to-NO 
converter that meets the converter conversion verification specified in 
Sec.  1065.378 at any point upstream of a NOX analyzer, 
sample bag, or other storage medium.
    (2) Sample dryer. You may use either type of sample dryer described 
in this paragraph (e)(2) to decrease the effects of water on gaseous 
emission measurements. You may not use a chemical dryer, or use dryers 
upstream of PM sample filters.
    (i) Osmotic-membrane. You may use an osmotic-membrane dryer upstream 
of any gaseous analyzer or storage medium, as long as it meets the 
temperature specifications in paragraph (d)(1) of this section. Because 
osmotic-membrane dryers may deteriorate after prolonged exposure to 
certain exhaust constituents, consult with the membrane manufacturer 
regarding your application before incorporating an osmotic-membrane 
dryer. Monitor the dewpoint, Tdew, and absolute pressure, 
ptotal, downstream of an osmotic-membrane dryer. You may use 
continuously recorded values of Tdew and ptotal in 
the amount of water calculations specified in Sec.  1065.645. For our 
testing we may use average temperature and pressure values over the test 
interval or a nominal pressure value that we estimate as the dryer's 
average pressure expected during testing as constant values in the 
amount of water calculations specified in Sec.  1065.645. For your 
testing, you may use the maximum temperature or minimum pressure values 
observed during a test interval or duty cycle or the high alarm 
temperature setpoint or low alarm pressure setpoint as constant values 
in the calculations specified in Sec.  1065.645. For your testing, you 
may also use a nominal ptotal, which you may estimate as the 
dryer's lowest absolute pressure expected during testing.
    (ii) Thermal chiller. You may use a thermal chiller upstream of some 
gas analyzers and storage media. You may not use a thermal chiller 
upstream of a THC measurement system for compression-ignition engines, 
two-stroke spark-ignition engines, or four-stroke spark-ignition engines 
at or below 19 kW. If you use a thermal chiller upstream of an 
NO2-to-NO converter or in a sampling system without an 
NO2-to-NO converter, the chiller must meet the NO2 
loss-performance check specified in Sec.  1065.376. Monitor the 
dewpoint,

[[Page 78]]

Tdew, and absolute pressure, p total, downstream 
of a thermal chiller. You may use continuously recorded values of 
Tdew and ptotal in the amount of water 
calculations specified in Sec.  1065.645. If it is valid to assume the 
degree of saturation in the thermal chiller, you may calculate T 
dew based on the known chiller performance and continuous 
monitoring of chiller temperature, Tchiller. If it is valid 
to assume a constant temperature offset between Tchiller and 
Tdew, due to a known and fixed amount of sample reheat 
between the chiller outlet and the temperature measurement location, you 
may factor in this assumed temperature offset value into emission 
calculations. If we ask for it, you must show by engineering analysis or 
by data the validity of any assumptions allowed by this paragraph 
(e)(2)(ii). For our testing we may use average temperature and pressure 
values over the test interval or a nominal pressure value that we 
estimate as the dryer's average pressure expected during testing as 
constant values in the calculations specified in Sec.  1065.645. For 
your testing you may use the maximum temperature and minimum pressure 
values observed during a test interval or duty cycle or the high alarm 
temperature setpoint and the low alarm pressure setpoint as constant 
values in the amount of water calculations specified in Sec.  1065.645. 
For your testing you may also use a nominal ptotal, which you 
may estimate as the dryer's lowest absolute pressure expected during 
testing.
    (3) Sample pumps. You may use sample pumps upstream of an analyzer 
or storage medium for any gas. Use sample pumps with inside surfaces of 
300 series stainless steel, PTFE, or any other material that you 
demonstrate has better properties for emission sampling. For some sample 
pumps, you must control temperatures, as follows:
    (i) If you use a NOX sample pump upstream of either an 
NO2-to-NO converter that meets Sec.  1065.378 or a chiller 
that meets Sec.  1065.376, design the sampling system to prevent aqueous 
condensation.
    (ii) For testing compression-ignition engines, two-stroke spark-
ignition engines, or four-stroke spark-ignition engines at or below 19 
kW, if you use a THC sample pump upstream of a THC analyzer or storage 
medium, its inner surfaces must be heated to a tolerance of (191 11) [deg]C.
    (4) Ammonia Scrubber. You may use ammonia scrubbers for any or all 
gaseous sampling systems to prevent interference with NH3, 
poisoning of the NO2-to-NO converter, and deposits in the 
sampling system or analyzers. Follow the ammonia scrubber manufacturer's 
recommendations or use good engineering judgment in applying ammonia 
scrubbers.
    (f) Optional sample-conditioning components for PM sampling. You may 
use the following sample-conditioning components to prepare PM samples 
for analysis, as long as you do not install or use them in a way that 
adversely affects your ability to show that your engines comply with the 
applicable PM emission standards. You may condition PM samples to 
minimize positive and negative biases to PM results, as follows:
    (1) PM preclassifier. You may use a PM preclassifier to remove 
large-diameter particles. The PM preclassifier may be either an inertial 
impactor or a cyclonic separator. It must be constructed of 300 series 
stainless steel. The preclassifier must be rated to remove at least 50% 
of PM at an aerodynamic diameter of 10 [micro]m and no more than 1% of 
PM at an aerodynamic diameter of 1 [micro]m over the range of flow rates 
for which you use it. Follow the preclassifier manufacturer's 
instructions for any periodic servicing that may be necessary to prevent 
a buildup of PM. Install the preclassifier in the dilution system 
downstream of the last dilution stage. Configure the preclassifier 
outlet with a means of bypassing any PM sample media so the 
preclassifier flow may be stabilized before starting a test. Locate PM 
sample media within 75 cm downstream of the preclassifier's exit. You 
may not use this preclassifier if you use a PM probe that already has a 
preclassifier. For example, if you use a hat-shaped preclassifier that 
is located immediately upstream of the probe in such a way that it 
forces the sample flow to change direction before entering the probe, 
you may not use any other

[[Page 79]]

preclassifier in your PM sampling system.
    (2) Other components. You may request to use other PM conditioning 
components upstream of a PM preclassifier, such as components that 
condition humidity or remove gaseous-phase hydrocarbons from the diluted 
exhaust stream. You may use such components only if we approve them 
under Sec.  1065.10.

[75 FR 23030, Apr. 30, 2010; 79 FR 23756, Apr. 28, 2014; 86 FR 34534, 
June 29, 2021; 88 FR 4670, Jan. 24, 2023]



Sec.  1065.150  Continuous sampling.

    You may use continuous sampling techniques for measurements that 
involve raw or dilute sampling. Make sure continuous sampling systems 
meet the specifications in Sec.  1065.145. Make sure continuous 
analyzers meet the specifications in subparts C and D of this part.



Sec.  1065.170  Batch sampling for gaseous and PM constituents.

    Batch sampling involves collecting and storing emissions for later 
analysis. Examples of batch sampling include collecting and storing 
gaseous emissions in a bag or collecting and storing PM on a filter. You 
may use batch sampling to store emissions that have been diluted at 
least once in some way, such as with CVS, PFD, or BMD. You may use batch 
sampling to store undiluted emissions. You may stop emission sampling 
anytime the engine is turned off, consistent with good engineering 
judgment. This is intended to allow for higher concentrations of dilute 
exhaust gases and more accurate measurements. Account for exhaust 
transport delay in the sampling system and integrate over the actual 
sampling duration when determining ndexh. Use good 
engineering judgment to add dilution air to fill bags up to minimum read 
volumes, as needed.
    (a) Sampling methods. If you extract from a constant-volume flow 
rate, sample at a constant-volume flow rate as follows:
    (1) Verify proportional sampling after an emission test as described 
in Sec.  1065.545. You must exclude from the proportional sampling 
verification any portion of the test where you are not sampling 
emissions because the engine is turned off and the batch samplers are 
not sampling, accounting for exhaust transport delay in the sampling 
system. Use good engineering judgment to select storage media that will 
not significantly change measured emission levels (either up or down). 
For example, do not use sample bags for storing emissions if the bags 
are permeable with respect to emissions or if they off gas emissions to 
the extent that it affects your ability to demonstrate compliance with 
the applicable gaseous emission standards in this chapter. As another 
example, do not use PM filters that irreversibly absorb or adsorb gases 
to the extent that it affects your ability to demonstrate compliance 
with the applicable PM emission standards in this chapter.
    (2) You must follow the requirements in Sec.  1065.140(e)(2) related 
to PM dilution ratios. For each filter, if you expect the net PM mass on 
the filter to exceed 400 [micro]g, assuming a 38 mm diameter filter 
stain area, you may take the following actions in sequence:
    (i) For discrete-mode testing only, you may reduce sample time as 
needed to target a filter loading of 400 [micro]g, but not below the 
minimum sample time specified in the standard-setting part.
    (ii) Reduce filter face velocity as needed to target a filter 
loading of 400 [micro]g, down to 50 cm/s or less.
    (iii) Increase overall dilution ratio above the values specified in 
Sec.  1065.140(e)(2) to target a filter loading of 400 [micro]g.
    (b) Gaseous sample storage media. Store gas volumes in sufficiently 
clean containers that minimally off-gas or allow permeation of gases. 
Use good engineering judgment to determine acceptable thresholds of 
storage media cleanliness and permeation. To clean a container, you may 
repeatedly purge and evacuate a container and you may heat it. Use a 
flexible container (such as a bag) within a temperature-controlled 
environment, or use a temperature controlled rigid container that is 
initially evacuated or has a volume that can be displaced, such as a 
piston and cylinder arrangement. Use containers meeting the 
specifications in the Table 1 of this section, noting that you may 
request to use other container

[[Page 80]]

materials under Sec.  1065.10. Sample temperatures must stay within the 
following ranges for each container material:
    (1) Up to 40 [deg]C for Tedlar \TM\ and Kynar \TM\..
    (2) (191 11) [deg]C for Teflon \TM\ and 300 
series stainless steel used with measuring THC or NMHC from compression-
ignition engines, two-stroke spark-ignition engines, and four-stroke 
spark-ignition engines at or below 19 kW. For all other engines and 
pollutants, these materials may be used for sample temperatures up to 
202 [deg]C.

    Table 1 of Sec.   1065.170--Container Materials for Gaseous Batch
                                Sampling
------------------------------------------------------------------------
                                                Engine type
                                 ---------------------------------------
                                     Compression-
                                     ignition Two-
            Emissions                stroke spark-
                                    ignition Four-     All other engines
                                     stroke spark-
                                    ignition at or
                                      below 19 kW
------------------------------------------------------------------------
CO, CO2, O2, CH4, C2H6, C3H8,     Tedlar \TM\, Kynar  Tedlar \TM\, Kynar
 NO, NO2, N2O.                     \TM\, Teflon        \TM\, Teflon
                                   \TM\, or 300        \TM\, or 300
                                   series stainless    series stainless
                                   steel.              steel.
THC, NMHC.......................  Teflon \TM\ or 300  Tedlar \TM\, Kynar
                                   series stainless    \TM\, Teflon
                                   steel.              \TM\, or 300
                                                       series stainless
                                                       steel.
------------------------------------------------------------------------

    (c) PM sample media. Apply the following methods for sampling 
particulate emissions:
    (1) If you use filter-based sampling media to extract and store PM 
for measurement, your procedure must meet the following specifications:
    (i) If you expect that a filter's total surface concentration of PM 
will exceed 400 [micro]g, assuming a 38 mm diameter filter stain area, 
for a given test interval, you may use filter media with a minimum 
initial collection efficiency of 98%; otherwise you must use a filter 
media with a minimum initial collection efficiency of 99.7%. Collection 
efficiency must be measured as described in ASTM D2986 (incorporated by 
reference in Sec.  1065.1010), though you may rely on the sample-media 
manufacturer's measurements reflected in their product ratings to show 
that you meet this requirement.
    (ii) The filter must be circular, with an overall diameter of (46.50 
0.60) mm and an exposed diameter of at least 38 
mm. See the cassette specifications in paragraph (c)(1)(vii) of this 
section.
    (iii) We highly recommend that you use a pure PTFE filter material 
that does not have any flow-through support bonded to the back and has 
an overall thickness of (40 20) [micro]m. An inert 
polymer ring may be bonded to the periphery of the filter material for 
support and for sealing between the filter cassette parts. We consider 
Polymethylpentene (PMP) and PTFE inert materials for a support ring, but 
other inert materials may be used. See the cassette specifications in 
paragraph (c)(1)(vii) of this section. We allow the use of PTFE-coated 
glass fiber filter material, as long as this filter media selection does 
not affect your ability to demonstrate compliance with the applicable 
standards in this chapter, which we base on a pure PTFE filter material. 
Note that we will use pure PTFE filter material for compliance testing, 
and we may require you to use pure PTFE filter material for any 
compliance testing we require, such as for selective enforcement audits.
    (iv) You may request to use other filter materials or sizes under 
the provisions of Sec.  1065.10.
    (v) To minimize turbulent deposition and to deposit PM evenly on a 
filter, use a filter holder with a 12.5[deg] (from center) divergent 
cone angle to transition from the transfer-line inside diameter to the 
exposed diameter of the filter face. Use 300 series stainless steel for 
this transition.
    (vi) Maintain a filter face velocity near 100 cm/s with less than 5% 
of the recorded flow values exceeding 100 cm/s, unless you expect the 
net PM mass on the filter to exceed 400 [micro]g, assuming a 38 mm 
diameter filter stain area. Measure face velocity as the volumetric flow 
rate of the sample at the pressure upstream of the filter and

[[Page 81]]

temperature of the filter face as measured in Sec.  1065.140(e), divided 
by the filter's exposed area. You may use the exhaust stack or CVS 
tunnel pressure for the upstream pressure if the pressure drop through 
the PM sampler up to the filter is less than 2 kPa.
    (vii) Use a clean cassette designed to the specifications of Figure 
1 of Sec.  1065.170. In auto changer configurations, you may use 
cassettes of similar design. Cassettes must be made of one of the 
following materials: Delrin \TM\, 300 series stainless steel, 
polycarbonate, acrylonitrile-butadiene-styrene (ABS) resin, or 
conductive polypropylene. We recommend that you keep filter cassettes 
clean by periodically washing or wiping them with a compatible solvent 
applied using a lint-free cloth. Depending upon your cassette material, 
ethanol (C2H5OH) might be an acceptable solvent. 
Your cleaning frequency will depend on your engine's PM and HC 
emissions.
    (viii) If you keep the cassette in the filter holder after sampling, 
prevent flow through the filter until either the holder or cassette is 
removed from the PM sampler. If you remove the cassettes from filter 
holders after sampling, transfer the cassette to an individual container 
that is covered or sealed to prevent communication of semi-volatile 
matter from one filter to another. If you remove the filter holder, cap 
the inlet and outlet. Keep them covered or sealed until they return to 
the stabilization or weighing environments.
    (ix) The filters should not be handled outside of the PM 
stabilization and weighing environments and should be loaded into 
cassettes, filter holders, or auto changer apparatus before removal from 
these environments.
    (2) You may use other PM sample media that we approve under Sec.  
1065.10, including non-filtering techniques. For example, you might 
deposit PM on an inert substrate that collects PM using electrostatic, 
thermophoresis, inertia, diffusion, or some other deposition mechanism, 
as approved.
[GRAPHIC] [TIFF OMITTED] TR25OC16.158


[[Page 82]]



[70 FR 40516, July 13, 2005, as amended at 73 FR 37298, June 30, 2008; 
73 FR 59321, Oct. 8, 2008; 76 FR 57440, Sept. 15, 2011;79 FR 23757, Apr. 
28, 2014; 81 FR 74162, Oct. 25, 2016; 86 FR 34534, June 29, 2021; 88 FR 
4671, Jan. 24, 2023]



Sec.  1065.190  PM-stabilization and weighing environments for 
gravimetric analysis.

    (a) This section describes the two environments required to 
stabilize and weigh PM for gravimetric analysis: the PM stabilization 
environment, where filters are stored before weighing; and the weighing 
environment, where the balance is located. The two environments may 
share a common space. These volumes may be one or more rooms, or they 
may be much smaller, such as a glove box or an automated weighing system 
consisting of one or more countertop-sized environments.
    (b) We recommend that you keep both the stabilization and the 
weighing environments free of ambient contaminants, such as dust, 
aerosols, or semi-volatile material that could contaminate PM samples. 
We recommend that these environments conform with an ``as-built'' Class 
Six clean room specification according to ISO 14644-1 (incorporated by 
reference in Sec.  1065.1010); however, we also recommend that you 
deviate from ISO 14644-1 as necessary to minimize air motion that might 
affect weighing. We recommend maximum air-supply and air-return 
velocities of 0.05 m/s in the weighing environment.
    (c) Verify the cleanliness of the PM-stabilization environment using 
reference filters, as described in Sec.  1065.390(d).
    (d) Maintain the following ambient conditions within the two 
environments during all stabilization and weighing:
    (1) Ambient temperature and tolerances. Maintain the weighing 
environment at a tolerance of (22 1) [deg]C. If 
the two environments share a common space, maintain both environments at 
a tolerance of (22 1) [deg]C. If they are 
separate, maintain the stabilization environment at a tolerance of (22 
3) [deg]C.
    (2) Dewpoint. Maintain a dewpoint of 9.5 [deg]C in both 
environments. This dewpoint will control the amount of water associated 
with sulfuric acid (H2SO4) PM, such that 1.2216 
grams of water will be associated with each gram of 
H2SO4.
    (3) Dewpoint tolerances. If the expected fraction of sulfuric acid 
in PM is unknown, we recommend controlling dewpoint at within 1 [deg]C tolerance. This would limit any dewpoint-
related change in PM to less than 2%, even for PM 
that is 50% sulfuric acid. If you know your expected fraction of 
sulfuric acid in PM, we recommend that you select an appropriate 
dewpoint tolerance for showing compliance with emission standards using 
the following table as a guide:

       Table 1 of Sec.   1065.190--Dewpoint Tolerance as a Function of % PM Change and % Sulfuric Acid PM
----------------------------------------------------------------------------------------------------------------
                                                                  0.5%    eq>1% PM mass change     eq>2% PM mass change
                PM                        PM mass change
----------------------------------------------------------------------------------------------------------------
5%................................  3     6  12 [deg]C
50%...............................  0.3   0.6 [deg]C.           eq>1.2 [deg]C
100%..............................  0.15  0.3 [deg]C.           eq>0.6 [deg]C
----------------------------------------------------------------------------------------------------------------

    (e) Verify the following ambient conditions using measurement 
instruments that meet the specifications in subpart C of this part:
    (1) Continuously measure dewpoint and ambient temperature. Use these 
values to determine if the stabilization and weighing environments have 
remained within the tolerances specified in paragraph (d) of this 
section for at least 60 min. before weighing sample media (e.g., 
filters). We recommend that you use an interlock that automatically 
prevents the balance from reporting values if either of the environments 
have not been within the applicable tolerances for the past 60 min.
    (2) Continuously measure atmospheric pressure within the weighing 
environment. An acceptable alternative

[[Page 83]]

is to use a barometer that measures atmospheric pressure outside the 
weighing environment, as long as you can ensure that atmospheric 
pressure at the balance is always within 100 Pa of 
that outside environment during weighing operations. Record atmospheric 
pressure as you weigh filters, and use these pressure values to perform 
the buoyancy correction in Sec.  1065.690.
    (f) We recommend that you install a balance as follows:
    (1) Install the balance on a vibration-isolation platform to isolate 
it from external noise and vibration.
    (2) Shield the balance from convective airflow with a static-
dissipating draft shield that is electrically grounded.
    (3) Follow the balance manufacturer's specifications for all 
preventive maintenance.
    (4) Operate the balance manually or as part of an automated weighing 
system.
    (g) Minimize static electric charge in the balance environment, as 
follows:
    (1) Electrically ground the balance.
    (2) Use 300 series stainless steel tweezers if PM sample media 
(e.g., filters) must be handled manually.
    (3) Ground tweezers with a grounding strap, or provide a grounding 
strap for the operator such that the grounding strap shares a common 
ground with the balance. Make sure grounding straps have an appropriate 
resistor to protect operators from accidental shock.
    (4) Provide a static-electricity neutralizer that is electrically 
grounded in common with the balance to remove static charge from PM 
sample media (e.g., filters), as follows:
    (i) You may use radioactive neutralizers such as a Polonium 
(\210\Po) source. Replace radioactive sources at the intervals 
recommended by the neutralizer manufacturer.
    (ii) You may use other neutralizers, such as corona-discharge 
ionizers. If you use a corona-discharge ionizer, we recommend that you 
monitor it for neutral net charge according to the ionizer 
manufacturer's recommendations.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37299, June 30, 2008; 
73 FR 59323, Oct. 8, 2008; 76 FR 57440, Sept. 15, 2011; 88 FR 4671, Jan. 
24, 2023]



Sec.  1065.195  PM-stabilization environment for in-situ analyzers.

    (a) This section describes the environment required to determine PM 
in-situ. For in-situ analyzers, such as an inertial balance, this is the 
environment within a PM sampling system that surrounds the PM sample 
media (e.g., filters). This is typically a very small volume.
    (b) Maintain the environment free of ambient contaminants, such as 
dust, aerosols, or semi-volatile material that could contaminate PM 
samples. Filter all air used for stabilization with HEPA filters. Ensure 
that HEPA filters are installed properly so that background PM does not 
leak past the HEPA filters.
    (c) Maintain the following thermodynamic conditions within the 
environment before measuring PM:
    (1) Ambient temperature. Select a nominal ambient temperature, Tamb, 
between (42 and 52) [deg]C. Maintain the ambient temperature within 
1.0 [deg]C of the selected nominal value.
    (2) Dewpoint. Select a dewpoint, Tdew, that corresponds to Tamb such 
that Tdew = (0.95Tamb-11.40) [deg]C. The resulting dewpoint will control 
the amount of water associated with sulfuric acid 
(H2SO4) PM, such that 1.1368 grams of water will 
be associated with each gram of H2SO4. For 
example, if you select a nominal ambient temperature of 47 [deg]C, set a 
dewpoint of 33.3 [deg]C.
    (3) Dewpoint tolerance. If the expected fraction of sulfuric acid in 
PM is unknown, we recommend controlling dewpoint within 1.0 [deg]C. This would limit any dewpoint-related change 
in PM to less than 2%, even for PM that is 50% 
sulfuric acid. If you know your expected fraction of sulfuric acid in 
PM, we recommend that you select an appropriate dewpoint tolerance for 
showing compliance with emission standards using Table 1 of Sec.  
1065.190 as a guide:

[[Page 84]]

    (4) Absolute pressure. Use good engineering judgment to maintain a 
tolerance of absolute pressure if your PM measurement instrument 
requires it.
    (d) Continuously measure dewpoint, temperature, and pressure using 
measurement instruments that meet the PM-stabilization environment 
specifications in subpart C of this part. Use these values to determine 
if the in-situ stabilization environment is within the tolerances 
specified in paragraph (c) of this section. Do not use any PM quantities 
that are recorded when any of these parameters exceed the applicable 
tolerances.
    (e) If you use an inertial PM balance, we recommend that you install 
it as follows:
    (1) Isolate the balance from any external noise and vibration that 
is within a frequency range that could affect the balance.
    (2) Follow the balance manufacturer's specifications.
    (f) If static electricity affects an inertial balance, you may use a 
static neutralizer, as follows:
    (1) You may use a radioactive neutralizer such as a Polonium 
(\210\Po) source or a Krypton (\85\Kr) source. Replace radioactive 
sources at the intervals recommended by the neutralizer manufacturer.
    (2) You may use other neutralizers, such as a corona-discharge 
ionizer. If you use a corona-discharge ionizer, we recommend that you 
monitor it for neutral net charge according to the ionizer 
manufacturer's recommendations.

[70 FR 40516, July 13, 2005, as amended at 73 FR 32799, June 30, 2008]



                    Subpart C_Measurement Instruments



Sec.  1065.201  Overview and general provisions.

    (a) Scope. This subpart specifies measurement instruments and 
associated system requirements related to emission testing in a 
laboratory or similar environment and in the field. This includes 
laboratory instruments and portable emission measurement systems (PEMS) 
for measuring engine parameters, ambient conditions, flow-related 
parameters, and emission concentrations.
    (b) Instrument types. You may use any of the specified instruments 
as described in this subpart to perform emission tests. If you want to 
use one of these instruments in a way that is not specified in this 
subpart, or if you want to use a different instrument, you must first 
get us to approve your alternate procedure under Sec.  1065.10. Where we 
specify more than one instrument for a particular measurement, we may 
identify which instrument serves as the reference for comparing with an 
alternate procedure. You may generally use instruments with compensation 
algorithms that are functions of other gaseous measurements and the 
known or assumed fuel properties for the test fuel. The target value for 
any compensation algorithm is 0% (that is, no bias high and no bias 
low), regardless of the uncompensated signal's bias.
    (c) Measurement systems. Assemble a system of measurement 
instruments that allows you to show that your engines comply with the 
applicable emission standards, using good engineering judgment. When 
selecting instruments, consider how conditions such as vibration, 
temperature, pressure, humidity, viscosity, specific heat, and exhaust 
composition (including trace concentrations) may affect instrument 
compatibility and performance.
    (d) Redundant systems. For all measurement instruments described in 
this subpart, you may use data from multiple instruments to calculate 
test results for a single test. If you use redundant systems, use good 
engineering judgment to use multiple measured values in calculations or 
to disregard individual measurements. Note that you must keep your 
results from all measurements. This requirement applies whether or not 
you actually use the measurements in your calculations.
    (e) Range. You may use an instrument's response above 100% of its 
operating range if this does not affect your ability to show that your 
engines comply with the applicable emission standards. Note that we 
require additional testing and reporting if an analyzer responds above 
100% of its range. Auto-

[[Page 85]]

ranging analyzers do not require additional testing or reporting.
    (f) Related subparts for laboratory testing. Subpart D of this part 
describes how to evaluate the performance of the measurement instruments 
in this subpart. In general, if an instrument is specified in a specific 
section of this subpart, its calibration and verifications are typically 
specified in a similarly numbered section in subpart D of this part. For 
example, Sec.  1065.290 gives instrument specifications for PM balances 
and Sec.  1065.390 describes the corresponding calibrations and 
verifications. Note that some instruments also have other requirements 
in other sections of subpart D of this part. Subpart B of this part 
identifies specifications for other types of equipment, and subpart H of 
this part specifies engine fluids and analytical gases.
    (g) Field testing and testing with PEMS. Subpart J of this part 
describes how to use these and other measurement instruments for field 
testing and other PEMS testing.
    (h) Recommended practices. This subpart identifies a variety of 
recommended but not required practices for proper measurements. We 
believe in most cases it is necessary to follow these recommended 
practices for accurate and repeatable measurements. However, we do not 
specifically require you to follow these recommended practices to 
perform a valid test, as long as you meet the required calibrations and 
verifications of measurement systems specified in subpart D of this 
part. Similarly, we are not required to follow all recommended 
practices, as long as we meet the required calibrations and 
verifications. Our decision to follow or not follow a given 
recommendation when we perform a test does not depend on whether you 
followed it during your testing.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37299, June 30, 2008; 
75 FR 23033, Apr. 30, 2010; 79 FR 23758, Apr. 29, 2014]



Sec.  1065.202  Data updating, recording, and control.

    Your test system must be able to update data, record data and 
control systems related to operator demand, the dynamometer, sampling 
equipment, and measurement instruments. Set up the measurement and 
recording equipment to avoid aliasing by ensuring that the sampling 
frequency is at least double that of the signal you are measuring, 
consistent with good engineering judgment; this may require increasing 
the sampling rate or filtering the signal. Use data acquisition and 
control systems that can record at the specified minimum frequencies, as 
follows:

                   Table 1 of Sec.   1065.202--Data Recording and Control Minimum Frequencies
----------------------------------------------------------------------------------------------------------------
                                                              Minimum command and
 Applicable test protocol section       Measured values        control frequency    Minimum recording frequency
                                                                      \a\                     \b\ \c\
----------------------------------------------------------------------------------------------------------------
Sec.   1065.510..................  Speed and torque during   1 Hz................  1 mean value per step.
                                    an engine step-map.
Sec.   1065.510..................  Speed and torque during   5 Hz................  1 Hz means.
                                    an engine sweep-map.
Sec.   1065.514; Sec.   1065.530.  Transient duty cycle      5 Hz................  1 Hz means.
                                    reference and feedback
                                    speeds and torques.
Sec.   1065.514; Sec.   1065.530.  Steady-state and ramped-  1 Hz................  1 Hz.
                                    modal duty cycle
                                    reference and feedback
                                    speeds and torques.
Sec.   1065.520; Sec.   1065.530;  Continuous                ....................  1 Hz.
 Sec.   1065.550.                   concentrations of raw
                                    or dilute analyzers.
Sec.   1065.520; Sec.   1065.530   Batch concentrations of   ....................  1 mean value per test
 Sec.   1065.550.                   raw or dilute analyzers.                        interval.
Sec.   1065.530; Sec.   1065.545.  Diluted exhaust flow      ....................  1 Hz.
                                    rate from a CVS with a
                                    heat exchanger upstream
                                    of the flow measurement.
Sec.   1065.530; Sec.   1065.545.  Diluted exhaust flow      5 Hz................  1 Hz means.
                                    rate from a CVS without
                                    a heat exchanger
                                    upstream of the flow
                                    measurement.
Sec.   1065.530; Sec.   1065.545.  Intake-air or raw-        ....................  1 Hz means.
                                    exhaust flow rate.

[[Page 86]]

 
Sec.   1065.530; Sec.   1065.545.  Dilution air flow if      5 Hz................  1 Hz means.
                                    actively controlled
                                    (for example, a partial-
                                    flow PM sampling
                                    system) \d\.
Sec.   1065.530; Sec.   1065.545.  Sample flow from a CVS    1 Hz................  1 Hz.
                                    that has a heat
                                    exchanger.
Sec.   1065.530; Sec.   1065.545.  Sample flow from a CVS    5 Hz................  1 Hz means.
                                    that does not have a
                                    heat exchanger.
----------------------------------------------------------------------------------------------------------------
\a\ The specifications for minimum command and control frequency do not apply for CFVs that are not using active
  control.
\b\ 1 Hz means are data reported from the instrument at a higher frequency, but recorded as a series of 1 s mean
  values at a rate of 1 Hz.
\c\ For CFVs in a CVS, the minimum recording frequency is 1 Hz. The minimum recording frequency does not apply
  for CFVs used to control sampling from a CVS utilizing CFVs.
\d\ Dilution air flow specifications do not apply for CVS dilution air.


[79 FR 23759, Apr. 28, 2014, as amended at 81 FR 74162, Oct. 25, 2016]



Sec.  1065.205  Performance specifications for measurement instruments.

    Your test system as a whole must meet all the calibrations, 
verifications, and test-validation criteria specified elsewhere in this 
part for laboratory testing or field testing, as applicable. We 
recommend that your instruments meet the specifications in this section 
for all ranges you use for testing. We also recommend that you keep any 
documentation you receive from instrument manufacturers showing that 
your instruments meet the specifications in the following table:

[[Page 87]]

[GRAPHIC] [TIFF OMITTED] TR29JN21.171


[[Page 88]]



[86 FR 34534, June 29, 2021]

         Measurement of Engine Parameters and Ambient Conditions



Sec.  1065.210  Work input and output sensors.

    (a) Application. Use instruments as specified in this section to 
measure work inputs and outputs during engine operation. We recommend 
that you use sensors, transducers, and meters that meet the 
specifications in Table 1 of Sec.  1065.205. Note that your overall 
systems for measuring work inputs and outputs must meet the linearity 
verifications in Sec.  1065.307. We recommend that you measure work 
inputs and outputs where they cross the system boundary as shown in 
Figure 1 of this section. The system boundary is different for air-
cooled engines than for liquid-cooled engines. If you choose to measure 
work before or after a work conversion, relative to the system boundary, 
use good engineering judgment to estimate any work-conversion losses in 
a way that avoids overestimation of total work. For example, if it is 
impractical to instrument the shaft of an exhaust turbine generating 
electrical work, you may decide to measure its converted electrical 
work. As another example, you may decide to measure the tractive (i.e., 
electrical output) power of a locomotive, rather than the brake power of 
the locomotive engine. In these cases, divide the electrical work by 
accurate values of electrical generator efficiency ([eta] <1), or assume 
an efficiency of 1 ([eta] =1), which would over-estimate brake-specific 
emissions. For the example of using locomotive tractive power with a 
generator efficiency of 1 ([eta] =1), this means using the tractive 
power as the brake power in emission calculations. Do not underestimate 
any work conversion efficiencies for any components outside the system 
boundary that do not return work into the system boundary. And do not 
overestimate any work conversion efficiencies for components outside the 
system boundary that do return work into the system boundary. In all 
cases, ensure that you are able to accurately demonstrate compliance 
with the applicable standards in this chapter. Figure 1 follows:

 Figure 1 to Paragraph (a) of Sec.  1065.210: Work Inputs, Outputs, and 
                            System Boundaries

[[Page 89]]

[GRAPHIC] [TIFF OMITTED] TR24JA23.103

    (b) Shaft work. Use speed and torque transducer outputs to calculate 
total work according to Sec.  1065.650.
    (1) Speed. Use a magnetic or optical shaft-position detector with a 
resolution of at least 60 counts per revolution, in combination with a 
frequency

[[Page 90]]

counter that rejects common-mode noise.
    (2) Torque. You may use a variety of methods to determine engine 
torque. As needed, and based on good engineering judgment, compensate 
for torque induced by the inertia of accelerating and decelerating 
components connected to the flywheel, such as the drive shaft and 
dynamometer rotor. Use any of the following methods to determine engine 
torque:
    (i) Measure torque by mounting a strain gage or similar instrument 
in-line between the engine and dynamometer.
    (ii) Measure torque by mounting a strain gage or similar instrument 
on a lever arm connected to the dynamometer housing.
    (iii) Calculate torque from internal dynamometer signals, such as 
armature current, as long as you calibrate this measurement as described 
in Sec.  1065.310.
    (c) Electrical work. Use a watt-hour meter output to calculate total 
work according to Sec.  1065.650. Use a watt-hour meter that outputs 
active power. Watt-hour meters typically combine a Wheatstone bridge 
voltmeter and a Hall-effect clamp-on ammeter into a single 
microprocessor-based instrument that analyzes and outputs several 
parameters, such as alternating or direct current voltage, current, 
power factor, apparent power, reactive power, and active power.
    (d) Pump, compressor or turbine work. Use pressure transducer and 
flow-meter outputs to calculate total work according to Sec.  1065.650. 
For flow meters, see Sec. Sec.  1065.220 through 1065.248.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37300, June 30, 2008; 
79 FR 23760, Apr. 28, 2014; 88 FR 4671, Jan. 24, 2023]



Sec.  1065.215  Pressure transducers, temperature sensors, and dewpoint sensors.

    (a) Application. Use instruments as specified in this section to 
measure pressure, temperature, and dewpoint.
    (b) Component requirements. We recommend that you use pressure 
transducers, temperature sensors, and dewpoint sensors that meet the 
specifications in Table 1 of Sec.  1065.205. Note that your overall 
systems for measuring pressure, temperature, and dewpoint must meet the 
calibration and verifications in Sec.  1065.315.
    (c) Temperature. For PM-balance environments or other precision 
temperature measurements over a narrow temperature range, we recommend 
thermistors. For other applications we recommend thermocouples that are 
not grounded to the thermocouple sheath. You may use other temperature 
sensors, such as resistive temperature detectors (RTDs).
    (d) Pressure. Pressure transducers must be located in a temperature-
controlled environment, or they must compensate for temperature changes 
over their expected operating range. Transducer materials must be 
compatible with the fluid being measured. For atmospheric pressure or 
other precision pressure measurements, we recommend either capacitance-
type, quartz crystal, or laser-interferometer transducers. For other 
applications, we recommend either strain gage or capacitance-type 
pressure transducers. You may use other pressure-measurement 
instruments, such as manometers, where appropriate.
    (e) Dewpoint. For PM-stabilization environments, we recommend 
chilled-surface hygrometers, which include chilled mirror detectors and 
chilled surface acoustic wave (SAW) detectors. For other applications, 
we recommend thin-film capacitance sensors. You may use other dewpoint 
sensors, such as a wet-bulb/dry-bulb psychrometer, where appropriate.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37300, June 30, 2008]

                        Flow-Related Measurements



Sec.  1065.220  Fuel flow meter.

    (a) Application. You may use fuel flow meters in combination with a 
chemical balance of fuel, DEF, intake air, and raw exhaust to calculate 
raw exhaust flow as described in Sec.  1065.655(f). You may also use 
fuel flow meters to determine the mass flow rate of carbon-carrying fuel 
streams for performing carbon balance error verification in Sec.  
1065.543 and to calculate the mass of those fuel streams as described in 
Sec.  1065.643. The following provisions apply for using fuel flow 
meters:

[[Page 91]]

    (1) Use the actual value of calculated raw exhaust flow rate in the 
following cases:
    (i) For multiplying raw exhaust flow rate with continuously sampled 
concentrations.
    (ii) For multiplying total raw exhaust flow with batch-sampled 
concentrations.
    (iii) For calculating the dilution air flow for background 
correction as described in Sec.  1065.667.
    (2) In the following cases, you may use a fuel flow meter signal 
that does not give the actual value of raw exhaust, as long as it is 
linearly proportional to the exhaust molar flow rate's actual calculated 
value:
    (i) For feedback control of a proportional sampling system, such as 
a partial-flow dilution system.
    (ii) For multiplying with continuously sampled gas concentrations, 
if the same signal is used in a chemical-balance calculation to 
determine work from brake-specific fuel consumption and fuel consumed.
    (b) Component requirements. We recommend that you use a fuel flow 
meter that meets the specifications in Table 1 of Sec.  1065.205. We 
recommend a fuel flow meter that measures mass directly, such as one 
that relies on gravimetric or inertial measurement principles. This may 
involve using a meter with one or more scales for weighing fuel or using 
a Coriolis meter. Note that your overall system for measuring fuel flow 
must meet the linearity verification in Sec.  1065.307 and the 
calibration and verifications in Sec.  1065.320.
    (c) Recirculating fuel. In any fuel-flow measurement, account for 
any fuel that bypasses the engine or returns from the engine to the fuel 
storage tank.
    (d) Flow conditioning. For any type of fuel flow meter, condition 
the flow as needed to prevent wakes, eddies, circulating flows, or flow 
pulsations from affecting the accuracy or repeatability of the meter. 
You may accomplish this by using a sufficient length of straight tubing 
(such as a length equal to at least 10 pipe diameters) or by using 
specially designed tubing bends, straightening fins, or pneumatic 
pulsation dampeners to establish a steady and predictable velocity 
profile upstream of the meter. Condition the flow as needed to prevent 
any gas bubbles in the fuel from affecting the fuel meter.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37300, June 30, 2008; 
76 FR 57441, Sept. 15, 2011; 81 FR 74162, Oct. 25, 2016; 86 FR 34536, 
June 29, 2021]



Sec.  1065.225  Intake-air flow meter.

    (a) Application. You may use intake-air flow meters in combination 
with a chemical balance of fuel, DEF, intake air, and raw exhaust to 
calculate raw exhaust flow as described in Sec.  1065.655(f) and (g). 
You may also use intake-air flow meters to determine the amount of 
intake air input for performing carbon balance error verification in 
Sec.  1065.543 and to calculate the measured amount of intake air, 
nint, as described in Sec.  1065.643. The following 
provisions apply for using intake air flow meters:
    (i) For multiplying raw exhaust flow rate with continuously sampled 
concentrations.
    (ii) For multiplying total raw exhaust flow with batch-sampled 
concentrations.
    (iii) For verifying minimum dilution ratio for PM batch sampling as 
described in Sec.  1065.546.
    (iv) For calculating the dilution air flow for background correction 
as described in Sec.  1065.667.
    (2) In the following cases, you may use an intake-air flow meter 
signal that does not give the actual value of raw exhaust, as long as it 
is linearly proportional to the exhaust flow rate's actual calculated 
value:
    (i) For feedback control of a proportional sampling system, such as 
a partial-flow dilution system.
    (ii) For multiplying with continuously sampled gas concentrations, 
if the same signal is used in a chemical-balance calculation to 
determine work from brake-specific fuel consumption and fuel consumed.
    (b) Component requirements. We recommend that you use an intake-air 
flow meter that meets the specifications in Table 1 of Sec.  1065.205. 
This may

[[Page 92]]

include a laminar flow element, an ultrasonic flow meter, a subsonic 
venturi, a thermal-mass meter, an averaging Pitot tube, or a hot-wire 
anemometer. Note that your overall system for measuring intake-air flow 
must meet the linearity verification in Sec.  1065.307 and the 
calibration in Sec.  1065.325.
    (c) Flow conditioning. For any type of intake-air flow meter, 
condition the flow as needed to prevent wakes, eddies, circulating 
flows, or flow pulsations from affecting the accuracy or repeatability 
of the meter. You may accomplish this by using a sufficient length of 
straight tubing (such as a length equal to at least 10 pipe diameters) 
or by using specially designed tubing bends, orifice plates or 
straightening fins to establish a predictable velocity profile upstream 
of the meter.

[70 FR 40516, July 13, 2005, as amended at 76 FR 57442, Sept. 15, 
2011;79 FR 23760, Apr. 28, 2014; 81 FR 74163, Oct. 25, 2016; 86 FR 
34536, June 29, 2021]



Sec.  1065.230  Raw exhaust flow meter.

    (a) Application. You may use measured raw exhaust flow, as follows:
    (1) Use the actual value of calculated raw exhaust in the following 
cases:
    (i) Multiply raw exhaust flow rate with continuously sampled 
concentrations.
    (ii) Multiply total raw exhaust with batch sampled concentrations.
    (2) In the following cases, you may use a raw exhaust flow meter 
signal that does not give the actual value of raw exhaust, as long as it 
is linearly proportional to the exhaust flow rate's actual calculated 
value:
    (i) For feedback control of a proportional sampling system, such as 
a partial-flow dilution system.
    (ii) For multiplying with continuously sampled gas concentrations, 
if the same signal is used in a chemical-balance calculation to 
determine work from brake-specific fuel consumption and fuel consumed.
    (b) Component requirements. We recommend that you use a raw-exhaust 
flow meter that meets the specifications in Table 1 of Sec.  1065.205. 
This may involve using an ultrasonic flow meter, a subsonic venturi, an 
averaging Pitot tube, a hot-wire anemometer, or other measurement 
principle. This would generally not involve a laminar flow element or a 
thermal-mass meter. Note that your overall system for measuring raw 
exhaust flow must meet the linearity verification in Sec.  1065.307 and 
the calibration and verifications in Sec.  1065.330. Any raw-exhaust 
meter must be designed to appropriately compensate for changes in the 
raw exhaust's thermodynamic, fluid, and compositional states.
    (c) Flow conditioning. For any type of raw exhaust flow meter, 
condition the flow as needed to prevent wakes, eddies, circulating 
flows, or flow pulsations from affecting the accuracy or repeatability 
of the meter. You may accomplish this by using a sufficient length of 
straight tubing (such as a length equal to at least 10 pipe diameters) 
or by using specially designed tubing bends, orifice plates or 
straightening fins to establish a predictable velocity profile upstream 
of the meter.
    (d) Exhaust cooling. You may cool raw exhaust upstream of a raw-
exhaust flow meter, as long as you observe all the following provisions:
    (1) Do not sample PM downstream of the cooling.
    (2) If cooling causes exhaust temperatures above 202 [deg]C to 
decrease to below 180 [deg]C, do not sample NMHC downstream of the 
cooling for compression-ignition engines, two-stroke spark-ignition 
engines, or four-stroke spark-ignition engines at or below 19 kW.
    (3) The cooling must not cause aqueous condensation.

[70 FR 40516, July 13, 2005, as amended at 79 FR 23761, Apr. 28, 2014]



Sec.  1065.240  Dilution air and diluted exhaust flow meters.

    (a) Application. Use a diluted exhaust flow meter to determine 
instantaneous diluted exhaust flow rates or total diluted exhaust flow 
over a test interval. You may use the difference between a diluted 
exhaust flow meter and a dilution air meter to calculate raw exhaust 
flow rates or total raw exhaust flow over a test interval.
    (b) Component requirements. We recommend that you use a diluted 
exhaust flow meter that meets the specifications in Table 1 of Sec.  
1065.205. Note that

[[Page 93]]

your overall system for measuring diluted exhaust flow must meet the 
linearity verification in Sec.  1065.307 and the calibration and 
verifications in Sec.  1065.340 and Sec.  1065.341. You may use the 
following meters:
    (1) For constant-volume sampling (CVS) of the total flow of diluted 
exhaust, you may use a critical-flow venturi (CFV) or multiple critical-
flow venturis arranged in parallel, a positive-displacement pump (PDP), 
a subsonic venturi (SSV), or an ultrasonic flow meter (UFM). Combined 
with an upstream heat exchanger, either a CFV or a PDP will also 
function as a passive flow controller in a CVS system. However, you may 
also combine any flow meter with any active flow control system to 
maintain proportional sampling of exhaust constituents. You may control 
the total flow of diluted exhaust, or one or more sample flows, or a 
combination of these flow controls to maintain proportional sampling.
    (2) For any other dilution system, you may use a laminar flow 
element, an ultrasonic flow meter, a subsonic venturi, a critical-flow 
venturi or multiple critical-flow venturis arranged in parallel, a 
positive-displacement meter, a thermal-mass meter, an averaging Pitot 
tube, or a hot-wire anemometer.
    (c) Flow conditioning. For any type of diluted exhaust flow meter, 
condition the flow as needed to prevent wakes, eddies, circulating 
flows, or flow pulsations from affecting the accuracy or repeatability 
of the meter. For some meters, you may accomplish this by using a 
sufficient length of straight tubing (such as a length equal to at least 
10 pipe diameters) or by using specially designed tubing bends, orifice 
plates or straightening fins to establish a predictable velocity profile 
upstream of the meter.
    (d) Exhaust cooling. You may cool diluted exhaust upstream of a 
dilute-exhaust flow meter, as long as you observe all the following 
provisions:
    (1) Do not sample PM downstream of the cooling.
    (2) If cooling causes exhaust temperatures above 202 [deg]C to 
decrease to below 180 [deg]C, do not sample NMHC downstream of the 
cooling for compression-ignition engines, two-stroke spark-ignition 
engines, or four-stroke spark-ignition engines at or below 19 kW.
    (3) The cooling must not cause aqueous condensation as described in 
Sec.  1065.140(c)(6).

[70 FR 40516, July 13, 2005, as amended at 75 FR 23035, Apr. 30, 2010; 
79 FR 23761, Apr. 28, 2014]



Sec.  1065.245  Sample flow meter for batch sampling.

    (a) Application. Use a sample flow meter to determine sample flow 
rates or total flow sampled into a batch sampling system over a test 
interval. You may use the difference between a diluted exhaust sample 
flow meter and a dilution air meter to calculate raw exhaust flow rates 
or total raw exhaust flow over a test interval.
    (b) Component requirements. We recommend that you use a sample flow 
meter that meets the specifications in Table 1 of Sec.  1065.205. This 
may involve a laminar flow element, an ultrasonic flow meter, a subsonic 
venturi, a critical-flow venturi or multiple critical-flow venturis 
arranged in parallel, a positive-displacement meter, a thermal-mass 
meter, an averaging Pitot tube, or a hot-wire anemometer. Note that your 
overall system for measuring sample flow must meet the linearity 
verification in Sec.  1065.307. For the special case where CFVs are used 
for both the diluted exhaust and sample-flow measurements and their 
upstream pressures and temperatures remain similar during testing, you 
do not have to quantify the flow rate of the sample-flow CFV. In this 
special case, the sample-flow CFV inherently flow-weights the batch 
sample relative to the diluted exhaust CFV.
    (c) Flow conditioning. For any type of sample flow meter, condition 
the flow as needed to prevent wakes, eddies, circulating flows, or flow 
pulsations from affecting the accuracy or repeatability of the meter. 
For some meters, you may accomplish this by using a sufficient length of 
straight tubing (such as a length equal to at least 10 pipe diameters) 
or by using specially designed tubing bends, orifice plates or 
straightening fins to establish a predictable velocity profile upstream 
of the meter.

[[Page 94]]



Sec.  1065.247  Diesel exhaust fluid flow rate.

    (a) Application. Determine diesel exhaust fluid (DEF) flow rate over 
a test interval for batch or continuous emission sampling using one of 
the three methods described in this section.
    (b) ECM. Use the ECM signal directly to determine DEF flow rate. You 
may combine this with a gravimetric scale if that improves measurement 
quality. Prior to testing, you may characterize the ECM signal using a 
laboratory measurement and adjust the ECM signal, consistent with good 
engineering judgment.
    (c) Flow meter. Measure DEF flow rate with a flow meter. We 
recommend that the flow meter that meets the specifications in Table 1 
of Sec.  1065.205. Note that your overall system for measuring DEF flow 
must meet the linearity verification in Sec.  1065.307. Measure using 
the following procedure:
    (1) Condition the flow of DEF as needed to prevent wakes, eddies, 
circulating flows, or flow pulsations from affecting the accuracy or 
repeatability of the meter. You may accomplish this by using a 
sufficient length of straight tubing (such as a length equal to at least 
10 pipe diameters) or by using specially designed tubing bends, 
straightening fins, or pneumatic pulsation dampeners to establish a 
steady and predictable velocity profile upstream of the meter. Condition 
the flow as needed to prevent any gas bubbles in the fluid from 
affecting the flow meter.
    (2) Account for any fluid that bypasses the DEF dosing unit or 
returns from the dosing unit to the fluid storage tank.
    (d) Gravimetric scale. Use a gravimetric scale to determine the mass 
of DEF the engine uses over a discrete-mode test interval and divide by 
the time of the test interval.

[86 FR 34536, June 29, 2021]



Sec.  1065.248  Gas divider.

    (a) Application. You may use a gas divider to blend calibration 
gases.
    (b) Component requirements. Use a gas divider that blends gases to 
the specifications of Sec.  1065.750 and to the flow-weighted 
concentrations expected during testing. You may use critical-flow gas 
dividers, capillary-tube gas dividers, or thermal-mass-meter gas 
dividers. Note that your overall gas-divider system must meet the 
linearity verification in Sec.  1065.307.

                   CO and CO2 Measurements



Sec.  1065.250  Nondispersive infrared analyzer.

    (a) Application. Use a nondispersive infrared (NDIR) analyzer to 
measure CO and CO2 concentrations in raw or diluted exhaust 
for either batch or continuous sampling.
    (b) Component requirements. We recommend that you use an NDIR 
analyzer that meets the specifications in Table 1 of Sec.  1065.205. 
Note that your NDIR-based system must meet the calibration and 
verifications in Sec. Sec.  1065.350 and 1065.355 and it must also meet 
the linearity verification in Sec.  1065.307.

[76 FR 57442, Sept. 15, 2011, as amended at 79 FR 23761, Apr. 28, 2014]

                        Hydrocarbon Measurements



Sec.  1065.260  Flame-ionization detector.

    (a) Application. Use a flame-ionization detector (FID) analyzer to 
measure hydrocarbon concentrations in raw or diluted exhaust for either 
batch or continuous sampling. Determine hydrocarbon concentrations on a 
carbon number basis of one, C1. For measuring THC or THCE you 
must use a FID analyzer. For measuring CH4 you must meet the 
requirements of paragraph (g) of this section. See subpart I of this 
part for special provisions that apply to measuring hydrocarbons when 
testing with oxygenated fuels.
    (b) Component requirements. We recommend that you use a FID analyzer 
that meets the specifications in Table 1 of Sec.  1065.205. Note that 
your FID-based system for measuring THC, THCE, or CH4 must 
meet all the verifications for hydrocarbon measurement in subpart D of 
this part, and it must also meet the linearity verification in Sec.  
1065.307.
    (c) Heated FID analyzers. For measuring THC or THCE from 
compression-ignition engines, two-stroke spark-ignition engines, and 
four-stroke spark-ignition engines at or below 19 kW, you

[[Page 95]]

must use heated FID analyzers that maintain all surfaces that are 
exposed to emissions at a temperature of (191 11) 
[deg]C.
    (d) FID fuel and burner air. Use FID fuel and burner air that meet 
the specifications of Sec.  1065.750. Do not allow the FID fuel and 
burner air to mix before entering the FID analyzer to ensure that the 
FID analyzer operates with a diffusion flame and not a premixed flame.
    (e) NMHC and NMOG. For demonstrating compliance with NMHC standards, 
you may either measure THC and determine NMHC mass as described in Sec.  
1065.660(b)(1), or you may measure THC and CH4 and determine 
NMHC as described in Sec.  1065.660(b)(2) or (3). You may also use the 
additive method in Sec.  1065.660(b)(4) for natural gas-fueled engines 
as described in Sec.  1065.266. See 40 CFR 1066.635 for methods to 
demonstrate compliance with NMOG standards for vehicle testing.
    (f) NMNEHC. For demonstrating compliance with NMNEHC standards, you 
may either measure NMHC or determine NMNEHC mass as described in Sec.  
1065.660(c)(1), you may measure THC, CH4, and 
C2H6 and determine NMNEHC as described in Sec.  
1065.660(c)(2), or you may use the additive method in Sec.  
1065.660(c)(3).
    (g) CH4. For reporting CH4 or for demonstrating 
compliance with CH4 standards, you may use a FID analyzer 
with a nonmethane cutter as described in Sec.  1065.265 or you may use a 
GC-FID as described in Sec.  1065.267. Determine CH4 as 
described in Sec.  1065.660(d).

[76 FR 57442, Sept. 15, 2011, as amended at 79 FR 23761, Apr. 28, 2014; 
81 FR 74163, Oct. 25, 2016; 86 FR 34536, June 29, 2021; 88 FR 4672, Jan. 
24, 2023]



Sec.  1065.265  Nonmethane cutter.

    (a) Application. You may use a nonmethane cutter to measure 
CH4 with a FID analyzer. A nonmethane cutter oxidizes all 
nonmethane hydrocarbons to CO2 and H2O. You may 
use a nonmethane cutter for raw or diluted exhaust for batch or 
continuous sampling.
    (b) System performance. Determine nonmethane-cutter performance as 
described in Sec.  1065.365 and use the results to calculate 
CH4 or NMHC emissions in Sec.  1065.660.
    (c) Configuration. Configure the nonmethane cutter with a bypass 
line if it is needed for the verification described in Sec.  1065.365.
    (d) Optimization. You may optimize a nonmethane cutter to maximize 
the penetration of CH4 and the oxidation of all other 
hydrocarbons. You may humidify a sample and you may dilute a sample with 
purified air or oxygen (O2) upstream of the nonmethane cutter 
to optimize its performance. You must account for any sample 
humidification and dilution in emission calculations.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37300, June 30, 2008; 
76 FR 57442, Sept. 15, 2011]



Sec.  1065.266  Fourier transform infrared analyzer.

    (a) Application. For engines that run only on natural gas, you may 
use a Fourier transform infrared (FTIR) analyzer to measure nonmethane 
hydrocarbon (NMHC) and nonmethane-nonethane hydrocarbon (NMNEHC) for 
continuous sampling. You may use an FTIR analyzer with any gaseous-
fueled engine, including dual-fuel and flexible-fuel engines, to measure 
CH4 and C2H6, for either batch or 
continuous sampling (for subtraction from THC).
    (b) Component requirements. We recommend that you use an FTIR 
analyzer that meets the specifications in Table 1 of Sec.  1065.205. 
Note that your FTIR-based system must meet the linearity verification in 
Sec.  1065.307. Use appropriate analytical procedures for interpretation 
of infrared spectra. For example, EPA Test Method 320 (see https://
www.epa.gov/emc/method-320-vapor-phase-organic-and-inorganic-emissions-
extractive-ftir) and ASTM D6348 (incorporated by reference in Sec.  
1065.1010) are considered valid methods for spectral interpretation. You 
must use heated FTIR analyzers that maintain all surfaces that are 
exposed to emissions at a temperature of (110 to 202) [deg]C.
    (c) Hydrocarbon species for NMHC and NMNEHC additive determination. 
To determine NMNEHC, measure ethene, ethyne, propane, propene, butane, 
formaldehyde, acetaldehyde, formic acid, and methanol. To determine

[[Page 96]]

NMHC, measure ethane in addition to those same hydrocarbon species. 
Determine NMHC and NMNEHC as described in Sec.  1065.660(b)(4) and Sec.  
1065.660(c)(3).
    (d) NMHC and NMNEHC CH4 and C2H6 
determination from subtraction of CH4 and 
C2H6 from THC. Determine CH4 as 
described in Sec.  1065.660(d)(2) and C2H6 as 
described Sec.  1065.660(e). Determine NMHC from subtraction of 
CH4 from THC as described in Sec.  1065.660(b)(3) and NMNEHC 
from subtraction of CH4 and C2H6 as 
described Sec.  1065.660(c)(2). Determine CH4 as described in 
Sec.  1065.660(d)(2) and C2H6 as described Sec.  
1065.660(e).
    (e) Interference verification. Perform interference verification for 
FTIR analyzers using the procedures of Sec.  1065.366. Certain 
interference gases can interfere with FTIR analyzers by causing a 
response similar to the hydrocarbon species of interest. When running 
the interference verification for these analyzers, use interference 
gases as follows:
    (1) The interference gases for CH4 are CO2, 
H2O, and C2H6.
    (2) The interference gases for C2H6 are 
CO2, H2O, and CH4.
    (3) The interference gases for other measured hydrocarbon species 
are CO2, H2O, CH4, and 
C2H6.

[81 FR 74163, Oct. 25, 2016, as amended at 86 FR 34536, June 29, 2021]



Sec.  1065.267  Gas chromatograph with a flame ionization detector.

    (a) Application. You may use a gas chromatograph with a flame 
ionization detector (GC-FID) to measure CH4 and 
C2H6 concentrations of diluted exhaust for batch 
sampling. While you may also use a nonmethane cutter to measure 
CH4, as described in Sec.  1065.265, use a reference 
procedure based on a gas chromatograph for comparison with any proposed 
alternate measurement procedure under Sec.  1065.10.
    (b) Component requirements. We recommend that you use a GC-FID that 
meets the specifications in Table 1 of Sec.  1065.205 and that the 
measurement be done according to SAE J1151 (incorporated by reference in 
Sec.  1065.1010). The GC-FID must meet the linearity verification in 
Sec.  1065.307.

[76 FR 57442, Sept. 15, 2011, as amended at 79 FR 23761, Apr. 28, 2014; 
81 FR 74163, Oct. 25, 2016]



Sec.  1065.269  Photoacoustic analyzer for ethanol and methanol.

    (a) Application. You may use a photoacoustic analyzer to measure 
ethanol and/or methanol concentrations in diluted exhaust for batch 
sampling.
    (b) Component requirements. We recommend that you use a 
photoacoustic analyzer that meets the specifications in Table 1 of Sec.  
1065.205. Note that your photoacoustic system must meet the verification 
in Sec.  1065.369 and it must also meet the linearity verification in 
Sec.  1065.307. Use an optical wheel configuration that gives analytical 
priority to measurement of the least stable components in the sample. 
Select a sample integration time of at least 5 seconds. Take into 
account sample chamber and sample line volumes when determining flush 
times for your instrument.

[79 FR 23761, Apr. 28, 2014]

             NOX and N2O Measurements



Sec.  1065.270  Chemiluminescent detector.

    (a) Application. You may use a chemiluminescent detector (CLD) to 
measure NOX concentration in raw or diluted exhaust for batch 
or continuous sampling. We generally accept a CLD for NOX 
measurement, even though it measures only NO and NO2, when 
coupled with an NO2-to-NO converter, since conventional 
engines and aftertreatment systems do not emit significant amounts of 
NOX species other than NO and NO2. Measure other 
NOX species if required by the standard-setting part. While 
you may also use other instruments to measure NOX, as 
described in Sec.  1065.272, use a reference procedure based on a 
chemiluminescent detector for comparison with any proposed alternate 
measurement procedure under Sec.  1065.10.
    (b) Component requirements. We recommend that you use a CLD that 
meets the specifications in Table 1 of Sec.  1065.205. Note that your 
CLD-based system must meet the quench verification in Sec.  1065.370 and 
it must also meet the linearity verification in Sec.  1065.307. You may 
use a heated or unheated CLD, and you may use a CLD that operates at 
atmospheric pressure or under a vacuum.

[[Page 97]]

    (c) NO2-to-NO converter. Place upstream of the CLD an internal or 
external NO2-to-NO converter that meets the verification in 
Sec.  1065.378. Configure the converter with a bypass line if it is 
needed to facilitate this verification.
    (d) Humidity effects. You must maintain all CLD temperatures to 
prevent aqueous condensation. If you remove humidity from a sample 
upstream of a CLD, use one of the following configurations:
    (1) Connect a CLD downstream of any dryer or chiller that is 
downstream of an NO2-to-NO converter that meets the 
verification in Sec.  1065.378.
    (2) Connect a CLD downstream of any dryer or thermal chiller that 
meets the verification in Sec.  1065.376.
    (e) Response time. You may use a heated CLD to improve CLD response 
time.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37300, June 30, 2008; 
76 FR 57442, Sept. 15, 2011; 79 FR 23761, Apr. 28, 2014]



Sec.  1065.272  Nondispersive ultraviolet analyzer.

    (a) Application. You may use a nondispersive ultraviolet (NDUV) 
analyzer to measure NOX concentration in raw or diluted 
exhaust for batch or continuous sampling. We generally accept an NDUV 
for NOX measurement, even though it measures only NO and 
NO2, since conventional engines and aftertreatment systems do 
not emit significant amounts of other NOX species. Measure 
other NOX species if required by the standard-setting part. 
Note that good engineering judgment may preclude you from using an NDUV 
analyzer if sampled exhaust from test engines contains oil (or other 
contaminants) in sufficiently high concentrations to interfere with 
proper operation.
    (b) Component requirements. We recommend that you use an NDUV 
analyzer that meets the specifications in Table 1 of Sec.  1065.205. 
Note that your NDUV-based system must meet the verifications in Sec.  
1065.372 and it must also meet the linearity verification in Sec.  
1065.307.
    (c) NO2-to-NO converter. If your NDUV analyzer measures only NO, 
place upstream of the NDUV analyzer an internal or external 
NO2-to-NO converter that meets the verification in Sec.  
1065.378. Configure the converter with a bypass to facilitate this 
verification.
    (d) Humidity effects. You must maintain NDUV temperature to prevent 
aqueous condensation, unless you use one of the following 
configurations:
    (1) Connect an NDUV downstream of any dryer or chiller that is 
downstream of an NO2-to-NO converter that meets the 
verification in Sec.  1065.378.
    (2) Connect an NDUV downstream of any dryer or thermal chiller that 
meets the verification in Sec.  1065.376.

[70 FR 40516, July 13, 2005, as amended at 73 FR 59323, Oct. 8, 2008; 76 
FR 57442, Sept. 15, 2011; 79 FR 23761, Apr. 28, 2014]



Sec.  1065.274  Zirconium dioxide (ZrO2) NOX analyzer.

    (a) Application. You may use a zirconia oxide (ZrO2) 
analyzer to measure NOX in raw exhaust for field-testing 
engines.
    (b) Component requirements. We recommend that you use a 
ZrO2 analyzer that meets the specifications in Table 1 of 
Sec.  1065.205. Note that your ZrO2-based system must meet 
the linearity verification in Sec.  1065.307.
    (c) Species measured. The ZrO2-based system must be able 
to measure and report NO and NO2 together as NOX. 
If the ZrO2-based system cannot measure all of the 
NO2, you may develop and apply correction factors based on 
good engineering judgment to account for this deficiency.
    (d) Interference. You must account for NH3 interference 
with the NOX measurement.

[88 FR 4673, Jan. 24, 2023]



Sec.  1065.275  N2O measurement devices.

    (a) General component requirements. We recommend that you use an 
analyzer that meets the specifications in Table 1 of Sec.  1065.205. 
Note that your system must meet the linearity verification in Sec.  
1065.307.
    (b) Instrument types. You may use any of the following analyzers to 
measure N2O:
    (1) Nondispersive infrared (NDIR) analyzer.
    (2) Fourier transform infrared (FTIR) analyzer. Use appropriate 
analytical procedures for interpretation of infrared spectra. For 
example, EPA Test

[[Page 98]]

Method 320 (see Sec.  1065.266(b)) and ASTM D6348 (incorporated by 
reference in Sec.  1065.1010) are considered valid methods for spectral 
interpretation.
    (3) Laser infrared analyzer. Examples of laser infrared analyzers 
are pulsed-mode high-resolution narrow band mid-infrared analyzers, and 
modulated continuous wave high-resolution narrow band mid-infrared 
analyzers.
    (4) Photoacoustic analyzer. Use an optical wheel configuration that 
gives analytical priority to measurement of the least stable components 
in the sample. Select a sample integration time of at least 5 seconds. 
Take into account sample chamber and sample line volumes when 
determining flush times for your instrument.
    (5) Gas chromatograph analyzer. You may use a gas chromatograph with 
an electron-capture detector (GC-ECD) to measure N2O 
concentrations of diluted exhaust for batch sampling.
    (i) You may use a packed or porous layer open tubular (PLOT) column 
phase of suitable polarity and length to achieve adequate resolution of 
the N2O peak for analysis. Examples of acceptable columns are 
a PLOT column consisting of bonded polystyrene-divinylbenzene or a 
Porapack Q packed column. Take the column temperature profile and 
carrier gas selection into consideration when setting up your method to 
achieve adequate N2O peak resolution.
    (ii) Use good engineering judgment to zero your instrument and 
correct for drift. You do not need to follow the specific procedures in 
Sec. Sec.  1065.530 and 1065.550(b) that would otherwise apply. For 
example, you may perform a span gas measurement before and after sample 
analysis without zeroing and use the average area counts of the pre-span 
and post-span measurements to generate a response factor (area counts/
span gas concentration), which you then multiply by the area counts from 
your sample to generate the sample concentration.
    (c) Interference verification. Perform interference verification for 
NDIR, FTIR, laser infrared analyzers, and photoacoustic analyzers using 
the procedures of Sec.  1065.375. Interference verification is not 
required for GC-ECD. Certain interference gases can positively interfere 
with NDIR, FTIR, and photoacoustic analyzers by causing a response 
similar to N2O. When running the interference verification 
for these analyzers, use interference gases as follows:
    (1) The interference gases for NDIR analyzers are CO, 
CO2, H2O, CH4, and SO2. Note 
that interference species, with the exception of H2O, are 
dependent on the N2O infrared absorption band chosen by the 
instrument manufacturer. For each analyzer determine the N2O 
infrared absorption band. For each N2O infrared absorption 
band, use good engineering judgment to determine which interference 
gases to use in the verification.
    (2) Use good engineering judgment to determine interference gases 
for FTIR, and laser infrared analyzers. Note that interference species, 
with the exception of H2O, are dependent on the 
N2O infrared absorption band chosen by the instrument 
manufacturer. For each analyzer determine the N2O infrared 
absorption band. For each N2O infrared absorption band, use 
good engineering judgment to determine interference gases to use in the 
verification.
    (3) The interference gases for photoacoustic analyzers are CO, 
CO2, and H2O.

[74 FR 56512, Oct. 30, 2009, as amended at 76 FR 57443, Sept. 15, 2011; 
78 FR 36398, June 17, 2013;79 FR 23761, Apr. 28, 2014; 81 FR 74163, Oct. 
25, 2016; 86 FR 34536, June 29, 2021]

                       O2 Measurements



Sec.  1065.280  Paramagnetic and magnetopneumatic O2 
detection analyzers.

    (a) Application. You may use a paramagnetic detection (PMD) or 
magnetopneumatic detection (MPD) analyzer to measure O2 
concentration in raw or diluted exhaust for batch or continuous 
sampling. You may use good engineering judgment to develop calculations 
that use O2 measurements with a chemical balance of fuel, 
DEF, intake air, and exhaust to calculate exhaust flow rate.
    (b) Component requirements. We recommend that you use a PMD or MPD 
analyzer that meets the specifications in Table 1 of Sec.  1065.205. 
Note that it

[[Page 99]]

must meet the linearity verification in Sec.  1065.307.

[73 FR 37300, June 30, 2008, as amended at 76 FR 57443, Sept. 15, 
2011;79 FR 23762, Apr. 28, 2014; 86 FR 34536, June 29, 2021]

                     Air-to-Fuel Ratio Measurements



Sec.  1065.284  Zirconium dioxide (ZrO2) air-fuel ratio and O2 analyzer.

    (a) Application. You may use a zirconia (ZrO2) analyzer 
to measure air-to-fuel ratio in raw exhaust for continuous sampling. You 
may use O2 measurements with intake air or fuel flow 
measurements to calculate exhaust flow rate according to Sec.  1065.650.
    (b) Component requirements. We recommend that you use a 
ZrO2 analyzer that meets the specifications in Table 1 of 
Sec.  1065.205. Note that your ZrO2-based system must meet 
the linearity verification in Sec.  1065.307.

[70 FR 40516, July 13, 2005, as amended at 76 FR 57443, Sept. 15, 2011; 
79 FR 23762, Apr. 28, 2014]

                             PM Measurements



Sec.  1065.290  PM gravimetric balance.

    (a) Application. Use a balance to weigh net PM on a sample medium 
for laboratory testing.
    (b) Component requirements. We recommend that you use a balance that 
meets the specifications in Table 1 of Sec.  1065.205. Note that your 
balance-based system must meet the linearity verification in Sec.  
1065.307. If the balance uses internal calibration weights for routine 
spanning and the weights do not meet the specifications in Sec.  
1065.790, the weights must be verified independently with external 
calibration weights meeting the requirements of Sec.  1065.790. While 
you may also use an inertial balance to measure PM, as described in 
Sec.  1065.295, use a reference procedure based on a gravimetric balance 
for comparison with any proposed alternate measurement procedure under 
Sec.  1065.10.
    (c) Pan design. We recommend that you use a balance pan designed to 
minimize corner loading of the balance, as follows:
    (1) Use a pan that centers the PM sample media (such as a filter) on 
the weighing pan. For example, use a pan in the shape of a cross that 
has upswept tips that center the PM sample media on the pan.
    (2) Use a pan that positions the PM sample as low as possible.
    (d) Balance configuration. Configure the balance for optimum 
settling time and stability at your location.

[73 FR 37300, June 30, 2008, as amended at 75 FR 68462, Nov. 8, 2010]



Sec.  1065.295  PM inertial balance for field-testing analysis.

    (a) Application. You may use an inertial balance to quantify net PM 
on a sample medium for field testing.
    (b) Component requirements. We recommend that you use a balance that 
meets the specifications in Table 1 of Sec.  1065.205. Note that your 
balance-based system must meet the linearity verification in Sec.  
1065.307. If the balance uses an internal calibration process for 
routine spanning and linearity verifications, the process must be NIST-
traceable.
    (c) Loss correction. You may use PM loss corrections to account for 
PM loss in the inertial balance, including the sample handling system.
    (d) Deposition. You may use electrostatic deposition to collect PM 
as long as its collection efficiency is at least 95%.

[73 FR 59259, Oct. 8, 2008, as amended at 75 FR 68462, Nov. 8, 2010; 76 
FR 57443, Sept. 15, 2011; 79 FR 23762, Apr. 28, 2014]



Sec.  1065.298  Correcting real-time PM measurement based on gravimetric 
PM filter measurement for field-testing analysis.

    (a) Application. You may quantify net PM on a sample medium for 
field testing with a continuous PM measurement with correction based on 
gravimetric PM filter measurement.
    (b) Measurement principles. Photoacoustic or electrical aerosol 
instruments used in field-testing typically under-report PM emissions. 
Apply the verifications and corrections described in this section to 
meet accuracy requirements.
    (c) Component requirements. (1) Gravimetric PM measurement must meet 
the laboratory measurement requirements of this part 1065, noting that 
there are specific exceptions to

[[Page 100]]

some laboratory requirements and specification for field testing given 
in Sec.  1065.905(d)(2). In addition to those exceptions, field testing 
does not require you to verify proportional flow control as specified in 
Sec.  1065.545. Note also that the linearity requirements of Sec.  
1065.307 apply only as specified in this section.
    (2) Check the calibration and linearity of the photoacoustic and 
electrical aerosol instruments according to the instrument 
manufacturer's instructions and the following recommendations:
    (i) For photoacoustic instruments we recommend one of the following:
    (A) Use a reference elemental carbon-based PM source to calibrate 
the instrument Verify the photoacoustic instrument by comparing results 
either to a gravimetric PM measurement collected on the filter or to an 
elemental carbon analysis of collected PM.
    (B) Use a light absorber that has a known amount of laser light 
absorption to periodically verify the instrument's calibration factor. 
Place the light absorber in the path of the laser beam. This 
verification checks the integrity of the microphone sensitivity, the 
power of the laser diode, and the performance of the analog-to-digital 
converter.
    (C) Verify that you meet the linearity requirements in Table 1 of 
Sec.  1065.307 by generating a maximum reference PM mass concentration 
(verified gravimetrically) and then using partial-flow sampling to 
dilute to various evenly distributed concentrations.
    (ii) For electrical aerosol instruments we recommend one of the 
following:
    (A) Use reference monodisperse or polydisperse PM-like particles 
with a mobility diameter or count median diameter greater than 45 nm. 
Use an electrometer or condensation particle counter that has a 
d50 at or below 10 nm to verify the reference values.
    (B) Verify that you meet the linearity requirements in Table 1 of 
Sec.  1065.307 using a maximum reference particle concentration, a zero-
reference concentration, and at least two other evenly distributed 
points. Use partial-flow dilution to create the additional reference PM 
concentrations. The difference between measured values from the 
electrical aerosol and reference instruments at each point must be no 
greater than 15% of the mean value from the two measurements at that 
point.
    (d) Loss correction. You may use PM loss corrections to account for 
PM loss in the sample handling system.
    (e) Correction. Develop a multiplicative correction factor to ensure 
that total PM measured by photoacoustic or electrical aerosol 
instruments equate to the gravimetric filter-based total PM measurement. 
Calculate the correction factor by dividing the mass of PM captured on 
the gravimetric filter by the quantity represented by the total 
concentration of PM measured by the instrument multiplied by the time 
over the test interval multiplied by the gravimetric filter sample flow 
rate.

[88 FR 4673, Jan. 24, 2023]



                Subpart D_Calibrations and Verifications



Sec.  1065.301  Overview and general provisions.

    (a) This subpart describes required and recommended calibrations and 
verifications of measurement systems. See subpart C of this part for 
specifications that apply to individual instruments.
    (b) You must generally use complete measurement systems when 
performing calibrations or verifications in this subpart. For example, 
this would generally involve evaluating instruments based on values 
recorded with the complete system you use for recording test data, 
including analog-to-digital converters. For some calibrations and 
verifications, we may specify that you disconnect part of the 
measurement system to introduce a simulated signal.
    (c) If we do not specify a calibration or verification for a portion 
of a measurement system, calibrate that portion of your system and 
verify its performance at a frequency consistent with any 
recommendations from the measurement-system manufacturer, consistent 
with good engineering judgment.

[[Page 101]]

    (d) Use NIST-traceable standards to the tolerances we specify for 
calibrations and verifications. Where we specify the need to use NIST-
traceable standards, you may alternatively use international standards 
recognized by the CIPM Mutual Recognition Arrangement that are not NIST-
traceable.

[70 FR 40516, July 13, 2005, as amended at 88 FR 4673, Jan. 24, 2023]



Sec.  1065.303  Summary of required calibration and verifications.

    The following table summarizes the required and recommended 
calibrations and verifications described in this subpart and indicates 
when these have to be performed:

     Table 1 of Sec.   1065.303--Summary of Required Calibration and
                              Verifications
------------------------------------------------------------------------
      Type of calibration or
           verification                      Minimum frequency a
------------------------------------------------------------------------
Sec.   1065.305: Accuracy,          Accuracy: Not required, but
 repeatability and noise.            recommended for initial
                                     installation. Repeatability: Not
                                     required, but recommended for
                                     initial installation.
                                    Noise: Not required, but recommended
                                     for initial installation.
Sec.   1065.307: Linearity
 verification.
                                    Speed: Upon initial installation,
                                     within 370 days before testing and
                                     after major maintenance.
                                    Torque: Upon initial installation,
                                     within 370 days before testing and
                                     after major maintenance.
                                    Electrical power, current, and
                                     voltage: Upon initial installation,
                                     within 370 days before testing and
                                     after major maintenance.b
                                    Fuel mass flow rate: Upon initial
                                     installation, within 370 days
                                     before testing, and after major
                                     maintenance.
                                    Fuel mass scale: Upon initial
                                     installation, within 370 days
                                     before testing, and after major
                                     maintenance.
                                    DEF mass flow rate: Upon initial
                                     installation, within 370 days
                                     before testing, and after major
                                     maintenance.c
                                    DEF mass scale: Upon initial
                                     installation, within 370 days
                                     before testing, and after major
                                     maintenance.
                                    Intake-air, dilution air, diluted
                                     exhaust, and batch sampler flow
                                     rates: Upon initial installation,
                                     within 370 days before testing and
                                     after major maintenance.d
                                    Raw exhaust flow rate: Upon initial
                                     installation, within 185 days
                                     before testing and after major
                                     maintenance.d
                                    Gas dividers: Upon initial
                                     installation, within 370 days
                                     before testing, and after major
                                     maintenance.
                                    Gas analyzers (unless otherwise
                                     noted): Upon initial installation,
                                     within 35 days before testing and
                                     after major maintenance.
                                    FTIR and photoacoustic analyzers:
                                     Upon initial installation, within
                                     370 days before testing and after
                                     major maintenance.
                                    GC-ECD: Upon initial installation
                                     and after major maintenance.
                                    PM balance: Upon initial
                                     installation, within 370 days
                                     before testing and after major
                                     maintenance.
                                    Pressure, temperature, and dewpoint:
                                     Upon initial installation, within
                                     370 days before testing and after
                                     major maintenance.
Sec.   1065.308: Continuous gas     Upon initial installation or after
 analyzer system response and        system modification that would
 updating-recording verification--   affect response.
 for gas analyzers not
 continuously compensated for
 other gas species.
Sec.   1065.309: Continuous gas     Upon initial installation or after
 analyzer system-response and        system modification that would
 updating-recording verification--   affect response.
 for gas analyzers continuously
 compensated for other gas species.
Sec.   1065.310: Torque...........  Upon initial installation and after
                                     major maintenance.
Sec.   1065.315: Pressure,          Upon initial installation and after
 temperature, dewpoint.              major maintenance.
Sec.   1065.320: Fuel flow........  Upon initial installation and after
                                     major maintenance.
Sec.   1065.325: Intake flow......  Upon initial installation and after
                                     major maintenance.
Sec.   1065.330: Exhaust flow.....  Upon initial installation and after
                                     major maintenance.
Sec.   1065.340: Diluted exhaust    Upon initial installation and after
 flow (CVS).                         major maintenance.
Sec.   1065.341: CVS and PFD flow   Upon initial installation, within 35
 verification (propane check).       days before testing, and after
                                     major maintenance.e
Sec.   1065.342 Sample dryer        For thermal chillers: Upon
 verification.                       installation and after major
                                     maintenance. For osmotic membranes;
                                     upon installation, within 35 days
                                     of testing, and after major
                                     maintenance.
Sec.   1065.345: Vacuum leak......  For laboratory testing: Upon initial
                                     installation of the sampling
                                     system, within 8 hours before the
                                     start of the first test interval of
                                     each duty-cycle sequence, and after
                                     maintenance such as pre-filter
                                     changes.

[[Page 102]]

 
                                    For field testing: After each
                                     installation of the sampling system
                                     on the vehicle, prior to the start
                                     of the field test, and after
                                     maintenance such as pre-filter
                                     changes.
Sec.   1065.350: CO2 NDIR H2O       Upon initial installation and after
 interference.                       major maintenance.
Sec.   1065.355: CO NDIR CO2 and    Upon initial installation and after
 H2O interference.                   major maintenance.
Sec.   1065.360: FID calibration    Calibrate all FID analyzers: upon
 THC FID optimization, and THC FID   initial installation and after
 verification.                       major maintenance.
                                    Optimize and determine CH4 response
                                     for THC FID analyzers: upon initial
                                     installation and after major
                                     maintenance.
                                    Verify CH4 response for THC FID
                                     analyzers: upon initial
                                     installation, within 185 days
                                     before testing, and after major
                                     maintenance.
                                    Verify C2H6 response for THC FID
                                     analyzers if used for NMNEHC
                                     determination: upon initial
                                     installation, within 185 days
                                     before testing, and after major
                                     maintenance.
Sec.   1065.362: Raw exhaust FID    For all FID analyzers: upon initial
 O2 interference.                    installation, and after major
                                     maintenance.
                                    For THC FID analyzers: upon initial
                                     installation, after major
                                     maintenance, and after FID
                                     optimization according to Sec.
                                     1065.360.
Sec.   1065.365: Nonmethane cutter  Upon initial installation, within
 penetration.                        185 days before testing, and after
                                     major maintenance.
Sec.   1065.366: Interference       Upon initial installation and after
 verification for FTIR analyzers.    major maintenance.
Sec.   1065.369: H2O, CO, and CO2   Upon initial installation and after
 interference verification for       major maintenance.
 ethanol photoacoustic analyzers.
Sec.   1065.370: CLD CO2 and H2O    Upon initial installation and after
 quench.                             major maintenance.
Sec.   1065.372: NDUV HC and H2O    Upon initial installation and after
 interference.                       major maintenance.
Sec.   1065.375: N2O analyzer       Upon initial installation and after
 interference.                       major maintenance.
Sec.   1065.376: Chiller NO2        Upon initial installation and after
 penetration.                        major maintenance.
Sec.   1065.378: NO2-to-NO          Upon initial installation, within 35
 converter conversion.               days before testing, and after
                                     major maintenance.
Sec.   1065.390: PM balance and     Independent verification: Upon
 weighing.                           initial installation, within 370
                                     days before testing, and after
                                     major maintenance.
                                    Zero, span, and reference sample
                                     verifications: Within 12 hours of
                                     weighing, and after major
                                     maintenance.
Sec.   1065.395: Inertial PM        Independent verification: Upon
 balance and weighing.               initial installation, within 370
                                     days before testing, and after
                                     major maintenance.
                                    Other verifications: Upon initial
                                     installation and after major
                                     maintenance.
------------------------------------------------------------------------
a Perform calibrations and verifications more frequently than we
  specify, according to measurement system manufacturer instructions and
  good engineering judgment.
b Perform linearity verification either for electrical power or for
  current and voltage.
c Linearity verification is not required if DEF flow rate comes directly
  from the ECM signal as described in Sec.   1065.247(b).
d Linearity verification is not required if the flow signal's accuracy
  is verified by carbon balance error verification as described in Sec.
   1065.307(e)(5) or a propane check as described in Sec.   1065.341.
e CVS and PFD flow verification (propane check) is not required for
  measurement systems verified by linearity verification as described in
  Sec.   1065.307 or carbon balance error verification as described in
  Sec.   1065.341(h).


[86 FR 34536, June 29, 2021]



Sec.  1065.305  Verifications for accuracy, repeatability, and noise.

    (a) This section describes how to determine the accuracy, 
repeatability, and noise of an instrument. Table 1 of Sec.  1065.205 
specifies recommended values for individual instruments.
    (b) We do not require you to verify instrument accuracy, 
repeatability, or noise.
    However, it may be useful to consider these verifications to define 
a specification for a new instrument, to verify the performance of a new 
instrument upon delivery, or to troubleshoot an existing instrument.
    (c) In this section we use the letter ``y'' to denote a generic 
measured quantity, the superscript over-bar to denote an arithmetic mean 
(such as y), and the subscript ``ref'' to denote the reference quantity 
being measured.
    (d) Conduct these verifications as follows:
    (1) Prepare an instrument so it operates at its specified 
temperatures, pressures, and flows. Perform any instrument linearization 
or calibration procedures prescribed by the instrument manufacturer.
    (2) Zero the instrument as you would before an emission test by 
introducing a zero signal. Depending on the instrument, this may be a 
zero-concentration gas, a reference signal, a set of reference 
thermodynamic conditions, or some combination of these. For gas

[[Page 103]]

analyzers, use a zero gas that meets the specifications of Sec.  
1065.750.
    (3) Span the instrument as you would before an emission test by 
introducing a span signal. Depending on the instrument, this may be a 
span-concentration gas, a reference signal, a set of reference 
thermodynamic conditions, or some combination of these. For gas 
analyzers, use a span gas that meets the specifications of Sec.  
1065.750.
    (4) Use the instrument to quantify a NIST-traceable reference 
quantity, yref. For gas analyzers the reference gas must meet 
the specifications of Sec.  1065.750. Select a reference quantity near 
the mean value expected during testing. For all gas analyzers, use a 
quantity near the flow-weighted mean concentration expected at the 
standard or expected during testing, whichever is greater. For noise 
verification, use the same zero gas from paragraph (d)(2) of this 
section as the reference quantity. In all cases, allow time for the 
instrument to stabilize while it measures the reference quantity. 
Stabilization time may include time to purge an instrument and time to 
account for its response.
    (5) Sample and record values for 30 seconds (you may select a longer 
sampling period if the recording update frequency is less than 0.5 Hz), 
record the arithmetic mean, yi and record the standard 
deviation, [sigma]i of the recorded values. Refer to Sec.  
1065.602 for an example of calculating arithmetic mean and standard 
deviation.
    (6) Also, if the reference quantity is not absolutely constant, 
which might be the case with a reference flow, sample and record values 
of yrefi for 30 seconds and record the arithmetic mean of the 
values, yref. Refer to Sec.  1065.602 for an example of calculating 
arithmetic mean.
    (7) Subtract the reference value, yref (or 
yrefi), from the arithmetic mean, yi. Record this 
value as the error, [epsi]i.
    (8) Repeat the steps specified in paragraphs (d)(2) through (7) of 
this section until you have ten arithmetic means (y1, 
y2, yi, ...y10), ten standard 
deviations, ([sigma]1, [sigma]2, 
[sigma]i,...[sigma]10), and ten errors 
([epsi]1, [epsi]2, 
[epsi]i,...[epsi]10).
    (9) Use the following values to quantify your measurements:
    (i) Accuracy. Instrument accuracy is the absolute difference between 
the reference quantity, yref (or yref), and the arithmetic mean of the 
ten yi, y values. Refer to the example of an accuracy calculation in 
Sec.  1065.602. We recommend that instrument accuracy be within the 
specifications in Table 1 of Sec.  1065.205.
    (ii) Repeatability. Repeatability is two times the standard 
deviation of the ten errors (that is, repeatability = 2 [middot] 
s[epsi]). Refer to the example of a standard-deviation calculation in 
Sec.  1065.602. We recommend that instrument repeatability be within the 
specifications in Table 1 of Sec.  1065.205.
    (iii) Noise. Noise is two times the root-mean-square of the ten 
standard deviations (that is, noise = 2 [middot] rms[sigma]) when the 
reference signal is a zero-quantity signal. Refer to the example of a 
root-mean-square calculation in Sec.  1065.602. We recommend that 
instrument noise be within the specifications in Table 1 of Sec.  
1065.205.
    (10) You may use a measurement instrument that does not meet the 
accuracy, repeatability, or noise specifications in Table 1 of Sec.  
1065.205, as long as you meet the following criteria:
    (i) Your measurement systems meet all the other required 
calibration, verification, and validation specifications that apply as 
specified in the regulations.
    (ii) The measurement deficiency does not adversely affect your 
ability to demonstrate compliance with the applicable standards in this 
chapter.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37301, June 30, 2008; 
75 FR 23037, Apr. 30, 2010; 79 FR 23763, Apr. 28, 2014; 88 FR 4673, Jan. 
24, 2023]



Sec.  1065.307  Linearity verification.

    (a) Scope and frequency. Perform linearity verification on each 
measurement system listed in Table 1 of this section at least as 
frequently as indicated in Table 1 of Sec.  1065.303, consistent with 
measurement system manufacturer's recommendations and good engineering 
judgment. The intent of linearity verification is to determine that a 
measurement system responds accurately and proportionally over the 
measurement range of interest. Linearity verification generally consists

[[Page 104]]

of introducing a series of at least 10 reference values to a measurement 
system. The measurement system quantifies each reference value. The 
measured values are then collectively compared to the reference values 
by using a least-squares linear regression and the linearity criteria 
specified in Table 1 of this section.
    (b) Performance requirements. If a measurement system does not meet 
the applicable linearity criteria referenced in Table 1 of this section, 
correct the deficiency by re-calibrating, servicing, or replacing 
components as needed. Repeat the linearity verification after correcting 
the deficiency to ensure that the measurement system meets the linearity 
criteria. Before you may use a measurement system that does not meet 
linearity criteria, you must demonstrate to us that the deficiency does 
not adversely affect your ability to demonstrate compliance with the 
applicable standards in this chapter.
    (c) Procedure. Use the following linearity verification protocol, or 
use good engineering judgment to develop a different protocol that 
satisfies the intent of this section, as described in paragraph (a) of 
this section:
    (1) In this paragraph (c), the letter ``y'' denotes a generic 
measured quantity, the superscript over-bar denotes an arithmetic mean 
(such as y), and the subscript ``ref'' denotes the known or 
reference quantity being measured.
    (2) Use good engineering judgment to operate a measurement system at 
normal operating conditions. This may include any specified adjustment 
or periodic calibration of the measurement system.
    (3) If applicable, zero the instrument as you would before an 
emission test by introducing a zero signal. Depending on the instrument, 
this may be a zero-concentration gas, a reference signal, a set of 
reference thermodynamic conditions, or some combination of these. For 
gas analyzers, use a zero gas that meets the specifications of Sec.  
1065.750 and introduce it directly at the analyzer port.
    (4) If applicable, span the instrument as you would before an 
emission test by introducing a span signal. Depending on the instrument, 
this may be a span-concentration gas, a reference signal, a set of 
reference thermodynamic conditions, or some combination of these. For 
gas analyzers, use a span gas that meets the specifications of Sec.  
1065.750 and introduce it directly at the analyzer port.
    (5) If applicable, after spanning the instrument, check zero with 
the same signal you used in paragraph (c)(3) of this section. Based on 
the zero reading, use good engineering judgment to determine whether or 
not to rezero and or re-span the instrument before continuing.
    (6) For all measured quantities, use the instrument manufacturer's 
recommendations and good engineering judgment to select reference 
values, yrefi, that cover a range of values that you expect would 
prevent extrapolation beyond these values during emission testing. We 
recommend selecting a zero reference signal as one of the reference 
values for the linearity verification. For pressure, temperature, 
dewpoint, power, current, voltage, photoacoustic analyzers, and GC-ECD 
linearity verifications, we recommend at least three reference values. 
For all other linearity verifications select at least ten reference 
values.
    (7) Use the instrument manufacturer's recommendations and good 
engineering judgment to select the order in which you will introduce the 
series of reference values. For example, you may select the reference 
values randomly to avoid correlation with previous measurements and to 
avoid hysteresis; you may select reference values in ascending or 
descending order to avoid long settling times of reference signals; or 
you may select values to ascend and then descend to incorporate the 
effects of any instrument hysteresis into the linearity verification.
    (8) Generate reference quantities as described in paragraph (d) of 
this section. For gas analyzers, use gas concentrations known to be 
within the specifications of Sec.  1065.750 and introduce them directly 
at the analyzer port.
    (9) Introduce a reference signal to the measurement instrument.
    (10) Allow time for the instrument to stabilize while it measures 
the value at

[[Page 105]]

the reference condition. Stabilization time may include time to purge an 
instrument and time to account for its response.
    (11) At a recording frequency of at least f Hz, specified in Table 1 
of Sec.  1065.205, measure the value at the reference condition for 30 
seconds (you may select a longer sampling period if the recording update 
frequency is less than 0.5 Hz) and record the arithmetic mean of the 
recorded values, yi. Refer to Sec.  1065.602 for an example 
of calculating an arithmetic mean.
    (12) Repeat the steps in paragraphs (c)(9) though (11) of this 
section until measurements are complete at each of the reference 
conditions.
    (13) Use the arithmetic means, yi, and reference values, 
yrefi, to calculate least-squares linear regression 
parameters and statistical values to compare to the minimum performance 
criteria specified in Table 1 of this section. Use the calculations for 
a floating intercept described in Sec.  1065.602. Using good engineering 
judgment, you may weight the results of individual data pairs (i.e., 
(yrefi, yi)), in the linear regression 
calculations.
    (d) Reference signals. This paragraph (d) describes recommended 
methods for generating reference values for the linearity-verification 
protocol in paragraph (c) of this section. Use reference values that 
simulate actual values, or introduce an actual value and measure it with 
a reference-measurement system. In the latter case, the reference value 
is the value reported by the reference-measurement system. Reference 
values and reference-measurement systems must be NIST-traceable. We 
recommend using calibration reference quantities that are NIST-traceable 
within 0.5% uncertainty, if not specified 
elsewhere in this part 1065. Use the following recommended methods to 
generate reference values or use good engineering judgment to select a 
different reference:
    (1) Speed. Run the engine or dynamometer at a series of steady-state 
speeds and use a strobe, photo tachometer, or laser tachometer to record 
reference speeds.
    (2) Torque. Use a series of calibration weights and a calibration 
lever arm to simulate engine torque. You may instead use the engine or 
dynamometer itself to generate a nominal torque that is measured by a 
reference load cell or proving ring in series with the torque-
measurement system. In this case, use the reference load cell 
measurement as the reference value. Refer to Sec.  1065.310 for a 
torque-calibration procedure similar to the linearity verification in 
this section.
    (3) Electrical power, current, and voltage. You must perform 
linearity verification for either electrical power meters, or for 
current and voltage meters. Perform linearity verifications using a 
reference meter and controlled sources of current and voltage. We 
recommend using a complete calibration system that is suitable for the 
electrical power distribution industry.
    (4) Fuel and DEF mass flow rate. Use a gravimetric reference 
measurement (such as a scale, balance, or mass comparator) and a 
container. Use a stopwatch or timer to measure the time intervals over 
which reference masses of fluid pass through the mass flow rate meter. 
Use good engineering judgment to correct the reference mass flowing 
through the mass flow rate meter for buoyancy effects from any tubes, 
temperature probes, or objects submerged in the fluid in the container 
that are not attached to the container. If the container has any tubes 
or wires connected to the container, recalibrate the gravimetric 
reference measurement device with them connected and at normal operating 
pressure using calibration weights that meet the requirements in Sec.  
1065.790. The corrected reference mass that flowed through the mass flow 
rate meter during a time interval divided by the duration of the time 
interval is the average reference mass flow rate. For meters that report 
a different quantity (such as actual volume, standard volume, or moles), 
convert the reported quantity to mass. For meters that report a 
cumulative quantity calculate the average measured mass flow rate as the 
difference in the reported cumulative mass during the time interval 
divided by the duration of the time interval. For measuring flow rate of 
gaseous fuel prevent condensation on the fuel container and any attached 
tubes, fittings, or regulators.

[[Page 106]]

    (5) Flow rates--inlet air, dilution air, diluted exhaust, raw 
exhaust, or sample flow. Use a reference flow meter with a blower or 
pump to simulate flow rates. Use a restrictor, diverter valve, a 
variable-speed blower or a variable-speed pump to control the range of 
flow rates. Use the reference meter's response as the reference values.
    (i) Reference flow meters. Because the flow range requirements for 
these various flows are large, we allow a variety of reference meters. 
For example, for diluted exhaust flow for a full-flow dilution system, 
we recommend a reference subsonic venturi flow meter with a restrictor 
valve and a blower to simulate flow rates. For inlet air, dilution air, 
diluted exhaust for partial-flow dilution, raw exhaust, or sample flow, 
we allow reference meters such as critical flow orifices, critical flow 
venturis, laminar flow elements, master mass flow standards, or Roots 
meters. Make sure the reference meter is calibrated and its calibration 
is NIST-traceable. If you use the difference of two flow measurements to 
determine a net flow rate, you may use one of the measurements as a 
reference for the other.
    (ii) Reference flow values. Because the reference flow is not 
absolutely constant, sample and record values of nrefi for 30 
seconds and use the arithmetic mean of the values, nref, as 
the reference value. Refer to Sec.  1065.602 for an example of 
calculating arithmetic mean.
    (6) Gas division. Use one of the two reference signals:
    (i) At the outlet of the gas-division system, connect a gas analyzer 
that meets the linearity verification described in this section and has 
not been linearized with the gas divider being verified. For example, 
verify the linearity of an analyzer using a series of reference 
analytical gases directly from compressed gas cylinders that meet the 
specifications of Sec.  1065.750. We recommend using a FID analyzer or a 
PMD or MPD O2 analyzer because of their inherent linearity. 
Operate this analyzer consistent with how you would operate it during an 
emission test. Connect a span gas containing only a single constituent 
of interest with balance of purified air or purified N2 to 
the gas-divider inlet. Use the gas-division system to divide the span 
gas with purified air or nitrogen. Select gas divisions that you 
typically use. Use a selected gas division as the measured value. Use 
the analyzer response divided by the span gas concentration as the 
reference gas-division value. Because the instrument response is not 
absolutely constant, sample and record values of xrefi for 30 
seconds and use the arithmetic mean of the values, xref, as 
the reference value. Refer to Sec.  1065.602 for an example of 
calculating arithmetic mean.
    (ii) Using good engineering judgment and the gas divider 
manufacturer's recommendations, use one or more reference flow meters to 
measure the flow rates of the gas divider and verify the gas-division 
value.
    (7) Continuous constituent concentration. For reference values, use 
a series of gas cylinders of known gas concentration containing only a 
single constituent of interest with balance of purified air or purified 
N2 or use a gas-division system that is known to be linear 
with a span gas. Gas cylinders, gas-division systems, and span gases 
that you use for reference values must meet the specifications of Sec.  
1065.750.
    (8) Temperature. You may perform the linearity verification for 
temperature measurement systems with thermocouples, RTDs, and 
thermistors by removing the sensor from the system and using a simulator 
in its place. Use a NIST-traceable simulator that is independently 
calibrated and, as appropriate, cold-junction-compensated. The simulator 
uncertainty scaled to absolute temperature must be less than 0.5% of 
Tmax. If you use this option, you must use sensors that the 
supplier states are accurate to better than 0.5% of Tmax 
compared with their standard calibration curve.
    (9) Mass. For linearity verification for gravimetric PM balances, 
fuel mass scales, and DEF mass scales, use external calibration weights 
that meet the requirements in Sec.  1065.790. Perform the linearity 
verification for fuel mass scales and DEF mass scales with the in-use 
container, installing all objects that interface with the container. For 
example, this includes all tubes, temperature probes, and objects 
submerged

[[Page 107]]

in the fluid in the container; it also includes tubes, fittings, 
regulators, and wires, and any other objects attached to the container. 
We recommend that you develop and apply appropriate buoyancy corrections 
for the configuration of your mass scale during normal testing, 
consistent with good engineering judgment. Account for the scale 
weighing a calibration weight instead of fluid if you calculate buoyancy 
corrections. You may also correct for the effect of natural convection 
currents from temperature differences between the container and ambient 
air. Prepare for linearity verification by taking the following steps 
for vented and unvented containers:
    (i) If the container is vented to ambient, fill the container and 
tubes with fluid above the minimum level used to trigger a fill 
operation; drain the fluid down to the minimum level; tare the scale; 
and perform the linearity verification.
    (ii) If the container is rigid and not vented, drain the fluid down 
to the minimum level; fill all tubes attached to the container to normal 
operating pressure; tare the scale; and perform the linearity 
verification.
    (e) Measurement systems that require linearity verification. Table 1 
of this section indicates measurement systems that require linearity 
verification, subject to the following provisions:
    (1) Perform linearity verification more frequently based on the 
instrument manufacturer's recommendation or good engineering judgment.
    (2) The expression ``xmin'' refers to the reference value 
used during linearity verification that is closest to zero. This is the 
value used to calculate the first tolerance in Table 1 of this section 
using the intercept, a0. Note that this value may be zero, 
positive, or negative depending on the reference values. For example, if 
the reference values chosen to validate a pressure transducer vary from 
-10 to -1 kPa, xmin is -1 kPa. If the reference values used 
to validate a temperature device vary from 290 to 390 K, xmin 
is 290 K.
    (3) The expression ``max'' generally refers to the absolute value of 
the reference value used during linearity verification that is furthest 
from zero. This is the value used to scale the first and third 
tolerances in Table 1 of this section using a0 and SEE. For 
example, if the reference values chosen to validate a pressure 
transducer vary from -10 to -1 kPa, then pmax is +10 kPa. If 
the reference values used to validate a temperature device vary from 290 
to 390 K, then Tmax is 390 K. For gas dividers where ``max'' 
is expressed as, xmax/xspan; xmax is 
the maximum gas concentration used during the verification, 
xspan is the undivided, undiluted, span gas concentration, 
and the resulting ratio is the maximum divider point reference value 
used during the verification (typically 1). The following are special 
cases where ``max'' refers to a different value:
    (i) For linearity verification of a PM balance, mmax is 
the typical mass of a PM filter.
    (ii) For linearity verification of a torque measurement system used 
with the engine's primary output shaft, Tmax is the 
manufacturer's specified peak torque of the lowest torque engine 
expected during testing.
    (iii) For linearity verification of a fuel mass scale, 
mmax is determined based on the range of engines and test 
interval durations expected during testing. It is the minimum, over all 
engines expected during testing, of the fuel consumption expected over 
the minimum test interval duration at the engine's maximum fuel rate. If 
the minimum test interval duration used during testing does not change 
with engine power or if the minimum test interval duration used during 
testing increases with engine power, mmax is given by Eq. 
1065.307-1. Calculate mmax using the following equation:
[GRAPHIC] [TIFF OMITTED] TR29JN21.172

Where:

mmax,fuel = the manufacturer's specified maximum fuel rate on 
          the lowest-power engine expected during testing.
tmin = the minimum test interval duration expected during 
          testing. If the minimum test interval duration decreases with 
          engine power, evaluate Eq. 1065.307-1 for the range of engines 
          expected during testing and use the minimum calculated value 
          of mmax,fuel scale.


[[Page 108]]


    (iv) For linearity verification of a DEF mass scale, mmax 
is 10% of the value determined for a fuel mass scale in paragraph 
(e)(3)(iii) of this section. You may determine mmax for a DEF 
mass scale by evaluating mmax for a fuel mass scale based 
only on the DEF-using engines expected during testing.
    (v) For linearity verification of a fuel flow rate meter, 
mmax is the manufacturer's specified maximum fuel rate of the 
lowest-power engine expected during testing.
    (vi) For linearity verification of a DEF flow rate meter, 
mmax is 10% of the manufacturer's specified maximum fuel rate 
of the lowest-power DEF-using engine expected during testing.
    (vii) For linearity verification of an intake-air flow rate meter, 
nmax is the manufacturer's specified maximum intake-air flow 
rate (converted to molar flow rate) of the lowest-power engine expected 
during testing.
    (viii) For linearity verification of a raw exhaust flow rate meter, 
nmax is the manufacturer's specified maximum exhaust flow 
rate (converted to molar flow rate) of the lowest-power engine expected 
during testing.
    (ix) For linearity verification of an electrical-power measurement 
system used to determine the engine's primary output shaft torque, 
Pmax is the manufacturer's specified maximum power of the 
lowest-power engine expected during testing.
    (x) For linearity verification of an electrical-current measurement 
system used to determine the engine's primary output shaft torque, 
Imax is the maximum current expected on the lowest-power 
engine expected during testing.
    (xi) For linearity verification of an electrical-voltage measurement 
system used to determine the engine's primary output shaft torque, 
Vmax is the minimum peak voltage expected on the range of 
engines expected during testing.
    (4) The specified ranges are inclusive. For example, a specified 
range of 0.98-1.02 for a1 means 0.98<=a1<=1.02.
    (5) Table 2 of this section describes optional verification 
procedures you may perform instead of linearity verification for certain 
systems. The following provisions apply for the alternative verification 
procedures:
    (i) Perform the propane check verification described in Sec.  
1065.341 at the frequency specified in Table 1 of Sec.  1065.303.
    (ii) Perform the carbon balance error verification described in 
Sec.  1065.543 on all test sequences that use the corresponding system. 
It must also meet the restrictions listed in Table 2 of this section. 
You may evaluate the carbon balance error verification multiple ways 
with different inputs to validate multiple flow-measurement systems.
    (6) You must meet the a1 criteria for these quantities 
only if the absolute value of the quantity is required, as opposed to a 
signal that is only linearly proportional to the actual value.
    (7) Linearity verification is required for the following temperature 
measurements:
    (i) The following temperature measurements always require linearity 
verification:
    (A) Air intake.
    (B) Aftertreatment bed(s), for engines tested with aftertreatment 
devices subject to cold-start testing.
    (C) Dilution air for gaseous and PM sampling, including CVS, double-
dilution, and partial-flow systems.
    (D) PM sample.
    (E) Chiller sample, for gaseous sampling systems that use thermal 
chillers to dry samples and use chiller temperature to calculate the 
dewpoint at the outlet of the chiller. For your testing, if you choose 
to use a high alarm temperature setpoint for the chiller temperature as 
a constant value in determining the amount of water removed from the 
emission sample, you may use good engineering judgment to verify the 
accuracy of the high alarm temperature setpoint instead of linearity 
verification on the chiller temperature. To verify that the alarm trip 
point value is no less than 2.0 [deg]C below the reference value at the 
trip point, we recommend that you input a reference simulated 
temperature signal below the alarm trip point and increase this signal 
until the high alarm trips.
    (F) Transmission oil.
    (G) Axle gear oil.

[[Page 109]]

    (ii) Linearity verification is required for the following 
temperature measurements if these temperature measurements are specified 
by the engine manufacturer:
    (A) Fuel inlet.
    (B) Air outlet to the test cell's charge air cooler air outlet, for 
engines tested with a laboratory heat exchanger that simulates an 
installed charge air cooler.
    (C) Coolant inlet to the test cell's charge air cooler, for engines 
tested with a laboratory heat exchanger that simulates an installed 
charge air cooler.
    (D) Oil in the sump/pan.
    (E) Coolant before the thermostat, for liquid-cooled engines.
    (8) Linearity verification is required for the following pressure 
measurements:
    (i) The following pressure measurements always require linearity 
verification:
    (A) Air intake restriction.
    (B) Exhaust back pressure as required in Sec.  1065.130(h).
    (C) Barometer.
    (D) CVS inlet gage pressure where the raw exhaust enters the tunnel.
    (E) Sample dryer, for gaseous sampling systems that use either 
osmotic-membrane or thermal chillers to dry samples. For your testing, 
if you choose to use a low alarm pressure setpoint for the sample dryer 
pressure as a constant value in determining the amount of water removed 
from the emission sample, you may use good engineering judgment to 
verify the accuracy of the low alarm pressure setpoint instead of 
linearity verification on the sample dryer pressure. To verify that the 
trip point value is no more than 4.0 kPa above the reference value at 
the trip point, we recommend that you input a reference pressure signal 
above the alarm trip point and decrease this signal until the low alarm 
trips.
    (ii) Linearity verification is required for the following pressure 
measurements if these pressure measurements are specified by the engine 
manufacturer:
    (A) The test cell's charge air cooler and interconnecting pipe 
pressure drop, for turbo-charged engines tested with a laboratory heat 
exchanger that simulates an installed charge air cooler.
    (B) Fuel outlet.
    (f) Performance criteria for measurement systems. Table 1 follows:

                                   Table 1 of Sec.   1065.307--Measurement Systems That Require Linearity Verification
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                                                   Linearity criteria
        Measurement system                   Quantity          -----------------------------------------------------------------------------------------
                                                                   [verbar]xmin(a1-1)+a0[verbar]          a1                 SEE               r \2\
--------------------------------------------------------------------------------------------------------------------------------------------------------
Speed.............................  fn........................  <=0.05% [middot]fnmax.............       0.98-1.02  <=2% [middot]fnmax..  =0.
                                                                                                                                                     990
Torque............................  T.........................  <=1% [middot] Tmax................       0.98-1.02  <=2% [middot] Tmax..  =0.
                                                                                                                                                     990
Electrical power..................  P.........................  <=1% [middot] Pmax................       0.98-1.02  <=2% [middot] Pmax..  =0.
                                                                                                                                                     990
Current...........................  I.........................  <=1% [middot] Imax................       0.98-1.02  <=2% [middot] Imax..  =0.
                                                                                                                                                     990
Voltage...........................  U.........................  <=1% [middot] Umax................       0.98-1.02  <=2% [middot] Umax..  =0.
                                                                                                                                                     990
Fuel flow rate....................  m.........................  <=1% [middot] mmax................       0.98-1.02  <=2% [middot] mmax..  =0.
                                                                                                                                                     990
Fuel mass scale...................  m.........................  <=0.3% [middot] mmax..............     0.996-1.004  <=0.4% [middot] mmax  =0.
                                                                                                                                                     999
DEF flow rate.....................  m.........................  <=1% [middot] mmax................       0.98-1.02  <=2% [middot] mmax..  =0.
                                                                                                                                                     990
DEF mass scale....................  m.........................  <=0.3% [middot] mmax..............     0.996-1.004  <=0.4% [middot] mmax  =0.
                                                                                                                                                     999
Intake-air flow rate \a\..........  n.........................  <=1% [middot] nmax................       0.98-1.02  <=2% [middot] nmax..  =0.
                                                                                                                                                     990
Dilution air flow rate \a\........  n.........................  <=1% [middot] nmax................       0.98-1.02  <=2% [middot] nmax..  =0.
                                                                                                                                                     990
Diluted exhaust flow rate \a\.....  n.........................  <=1% [middot] nmax................       0.98-1.02  <=2% [middot] nmax..  =0.
                                                                                                                                                     990
Raw exhaust flow rate \a\.........  n.........................  <=1% [middot] nmax................       0.98-1.02  <=2% [middot]nmax...  =0.
                                                                                                                                                     990
Batch sampler flow rates \a\......  n.........................  <=1% [middot] nmax................       0.98-1.02  <=2% [middot]nmax...  =0.
                                                                                                                                                     990
Gas dividers......................  x/xspan...................  <=0.5% [middot] xmax/xspan........       0.98-1.02  <=2% [middot] xmax/   =0.
                                                                                                                     xspan.                          990
Gas analyzers for laboratory        x.........................  <=0.5% [middot] xmax..............       0.99-1.01  <=1% [middot] xmax..  =0.
 testing.                                                                                                                                            998
Gas analyzers for field testing...  x.........................  <=1% [middot] xmax................       0.99-1.01  <=1% [middot] xmax..  =0.
                                                                                                                                                     998
Electrical aerosol analyzer for     x.........................  <=5% [middot] xmax................       0.85-1.15  <=10% [middot] xmax.  =0.
 field testing.                                                                                                                                      950
Photoacoustic analyzer for field    x.........................  <=5% [middot] xmax................       0.90-1.10  <=10% [middot] xmax.  =0.
 testing.                                                                                                                                            980
PM balance........................  m.........................  <=1% [middot] mmax................       0.99-1.01  <=1% [middot] mmax..  =0.
                                                                                                                                                     998
Pressures.........................  p.........................  <=1% [middot] pmax................       0.99-1.01  <=1% [middot] pmax..  =0.
                                                                                                                                                     998
Dewpoint for intake air, PM-        Tdew......................  <=0.5% [middot] Tdewmax...........       0.99-1.01  <=0.5%                =0.
 stabilization and balance                                                                                           [middot]Tdewmax.                998
 environments.

[[Page 110]]

 
Other dewpoint measurements.......  Tdew......................  <=1% [middot] Tdewmax.............       0.99-1.01  <=1% [middot]         =0.
                                                                                                                     Tdewmax.                        998
Analog-to-digital conversion of     T.........................  <=1% [middot] Tmax................       0.99-1.01  <=1% [middot] Tmax..  =0.
 temperature signals.                                                                                                                                998
--------------------------------------------------------------------------------------------------------------------------------------------------------
\a\ For flow meters that determine volumetric flow rate, Vstd, you may substitute Vstd for n as the quantity and substitute Vstdmax for nmax.

    (g) Alternative verification procedures. Table 2 follows:

                   Table 2 of Sec.   1065.307--Optional Verification to Linearity Verification
----------------------------------------------------------------------------------------------------------------
                                                                                           Restrictions for Sec.
         Measurement system               Sec.   1065.341            Sec.   1065.543               1065.543
----------------------------------------------------------------------------------------------------------------
Intake-air flow rate...............  Yes......................  Yes......................  Determine raw exhaust
                                                                                            flow rate using the
                                                                                            intake-air flow rate
                                                                                            signal as an input
                                                                                            into Eq. 1065.655-24
                                                                                            and determine mass
                                                                                            of CO2 over each
                                                                                            test interval input
                                                                                            into Eq. 1065.643-6
                                                                                            using samples taken
                                                                                            from the raw exhaust
                                                                                            (continuous or bag,
                                                                                            and with or without
                                                                                            a PFD).
Dilution air flow rate for CVS.....  Yes......................  No.......................  Not allowed.
Diluted exhaust flow rate for CVS..  Yes......................  Yes......................  Determine mass of CO2
                                                                                            over each test
                                                                                            interval input into
                                                                                            Eq. 1065.643-6 using
                                                                                            samples taken from
                                                                                            the CVS (continuous
                                                                                            or bag, and with or
                                                                                            without a PFD).
Raw exhaust flow rate for exhaust    Yes......................  Yes......................  Determine mass of CO2
 stack.                                                                                     over each test
                                                                                            interval input into
                                                                                            Eq. 1065.643-6 using
                                                                                            samples taken from
                                                                                            the raw exhaust
                                                                                            (continuous or bag,
                                                                                            and with or without
                                                                                            a PFD).
Flow measurements in a PFD (usually  Yes......................  Yes......................  Determine mass of CO2
 dilution air and diluted exhaust                                                           over each test
 streams) used to determine the                                                             interval input into
 dilution ratio in the PFD.                                                                 Eq. 1065.643-6 using
                                                                                            samples taken from
                                                                                            the PFD (continuous
                                                                                            or bag).
Batch sampler flow rates...........  Yes......................  No.......................  Not allowed.
Fuel mass flow rate................  No.......................  Yes......................  Determine mass of a
                                                                                            carbon-carrying
                                                                                            fluid stream used as
                                                                                            an input into Eq.
                                                                                            1065.643-1 using the
                                                                                            fuel mass flow rate
                                                                                            meter.
Fuel mass scale....................  No.......................  Yes......................  Determine mass of a
                                                                                            carbon-carrying
                                                                                            fluid stream used as
                                                                                            an input into Eq.
                                                                                            1065.643-1 using the
                                                                                            fuel mass scale.
----------------------------------------------------------------------------------------------------------------


[79 FR 23763, Apr. 28, 2014, as amended at 86 FR 34538, June 29, 2021; 
87 FR 64865, Oct. 26, 2022; 88 FR 4673, Jan. 24, 2023]



Sec.  1065.308  Continuous gas analyzer system-response and updating
-recording verification--for gas analyzers not continuously
compensated for other gas 
          species.

    (a) Scope and frequency. This section describes a verification 
procedure for system response and updating-recording frequency for 
continuous gas analyzers that output a gas species mole fraction (i.e., 
concentration) using a single gas detector, i.e., gas analyzers not 
continuously compensated for other gas species measured with multiple 
gas detectors. See Sec.  1065.309 for verification procedures that apply 
to continuous gas analyzers that are continuously compensated for other 
gas species measured with multiple gas detectors. Perform this 
verification to determine the system response of the continuous gas 
analyzer and its sampling system. This verification is required for 
continuous gas analyzers used for transient or ramped-modal testing. You 
need not perform this verification for batch gas analyzer systems or for 
continuous gas analyzer

[[Page 111]]

systems that are used only for discrete-mode testing. Perform this 
verification after initial installation (i.e., test cell commissioning) 
and after any modifications to the system that would change system 
response. For example, perform this verification if you add a 
significant volume to the transfer lines by increasing their length or 
adding a filter; or if you reduce the frequency at which the gas 
analyzer updates its output or the frequency at which you sample and 
record gas-analyzer concentrations.
    (b) Measurement principles. This test verifies that the updating and 
recording frequencies match the overall system response to a rapid 
change in the value of concentrations at the sample probe. Gas analyzers 
and their sampling systems must be optimized such that their overall 
response to a rapid change in concentration is updated and recorded at 
an appropriate frequency to prevent loss of information. This test also 
verifies that the measurement system meets a minimum response time. You 
may use the results of this test to determine transformation time, 
t50, for the purposes of time alignment of continuous data in 
accordance with Sec.  1065.650(c)(2)(i). You may also use an alternate 
procedure to determine t50 in accordance with good 
engineering judgment. Note that any such procedure for determining 
t50 must account for both transport delay and analyzer 
response time.
    (c) System requirements. Demonstrate that each continuous analyzer 
has adequate update and recording frequencies and has a minimum rise 
time and a minimum fall time during a rapid change in gas concentration. 
You must meet one of the following criteria:
    (1) The product of the mean rise time, t10-90, and the 
frequency at which the system records an updated concentration must be 
at least 5, and the product of the mean fall time, t90-10, 
and the frequency at which the system records an updated concentration 
must be at least 5. If the recording frequency is different than the 
analyzer's output update frequency, you must use the lower of these two 
frequencies for this verification, which is referred to as the updating-
recording frequency. This verification applies to the nominal updating 
and recording frequencies. This criterion makes no assumption regarding 
the frequency content of changes in emission concentrations during 
emission testing; therefore, it is valid for any testing. Also, the mean 
rise time must be at or below 10 seconds and the mean fall time must be 
at or below 10 seconds.
    (2) The frequency at which the system records an updated 
concentration must be at least 5 Hz. This criterion assumes that the 
frequency content of significant changes in emission concentrations 
during emission testing do not exceed 1 Hz. Also, the mean rise time 
must be at or below 10 seconds and the mean fall time must be at or 
below 10 seconds.
    (3) You may use other criteria if we approve the criteria in 
advance.
    (4) You may meet the overall PEMS verification in Sec.  1065.920 
instead of the verification in this section for field testing with PEMS.
    (d) Procedure. Use the following procedure to verify the response of 
each continuous gas analyzer:
    (1) Instrument setup. Follow the analyzer manufacturer's start-up 
and operating instructions. Adjust the measurement system as needed to 
optimize performance. Run this verification with the analyzer operating 
in the same manner you will use for emission testing. If the analyzer 
shares its sampling system with other analyzers, and if gas flow to the 
other analyzers will affect the system response time, then start up and 
operate the other analyzers while running this verification test. You 
may run this verification test on multiple analyzers sharing the same 
sampling system at the same time. If you use any analog or real-time 
digital filters during emission testing, you must operate those filters 
in the same manner during this verification.
    (2) Equipment setup. We recommend using minimal lengths of gas 
transfer lines between all connections and fast-acting three-way valves 
(2 inlets, 1 outlet) to control the flow of zero and blended span gases 
to the sample system's probe inlet or a tee near the outlet of the 
probe. If you inject the gas at a tee near the outlet of the probe, you 
may correct the transformation time, t50, for an estimate of 
the transport

[[Page 112]]

time from the probe inlet to the tee. Normally the gas flow rate is 
higher than the sample flow rate and the excess is overflowed out the 
inlet of the probe. If the gas flow rate is lower than the sample flow 
rate, the gas concentrations must be adjusted to account for the 
dilution from ambient air drawn into the probe. We recommend you use the 
final, stabilized analyzer reading as the final gas concentration. 
Select span gases for the species being measured. You may use binary or 
multi-gas span gases. You may use a gas blending or mixing device to 
blend span gases. A gas blending or mixing device is recommended when 
blending span gases diluted in N2 with span gases diluted in 
air. You may use a multi-gas span gas, such as NO-CO-CO2-
C3H8-CH4, to verify multiple analyzers 
at the same time. If you use standard binary span gases, you must run 
separate response tests for each analyzer. In designing your 
experimental setup, avoid pressure pulsations due to stopping the flow 
through the gas-blending device. The change in gas concentration must be 
at least 20% of the analyzer's range.
    (3) Data collection. (i) Start the flow of zero gas.
    (ii) Allow for stabilization, accounting for transport delays and 
the slowest analyzer's full response.
    (iii) Start recording data. For this verification you must record 
data at a frequency greater than or equal to that of the updating-
recording frequency used during emission testing. You may not use 
interpolation or filtering to alter the recorded values.
    (iv) Switch the flow to allow the blended span gases to flow to the 
analyzer. If you intend to use the data from this test to determine 
t50 for time alignment, record this time as t0.
    (v) Allow for transport delays and the slowest analyzer's full 
response.
    (vi) Switch the flow to allow zero gas to flow to the analyzer. If 
you intend to use the data from this test to determine t50 
for time alignment, record this time as t100.
    (vii) Allow for transport delays and the slowest analyzer's full 
response.
    (viii) Repeat the steps in paragraphs (d)(3)(iv) through (vii) of 
this section to record seven full cycles, ending with zero gas flowing 
to the analyzers.
    (ix) Stop recording.
    (e) Performance evaluation. (1) If you choose to demonstrate 
compliance with paragraph (c)(1) of this section, use the data from 
paragraph (d)(3) of this section to calculate the mean rise time, 
t10-90, and mean fall time, t90-10, for each of 
the analyzers being verified. You may use interpolation between recorded 
values to determine rise and fall times. If the recording frequency used 
during emission testing is different from the analyzer's output update 
frequency, you must use the lower of these two frequencies for this 
verification. Multiply these times (in seconds) by their respective 
updating-recording frequencies in Hertz (1/second). The resulting 
product must be at least 5 for both rise time and fall time. If either 
value is less than 5, increase the updating-recording frequency, or 
adjust the flows or design of the sampling system to increase the rise 
time and fall time as needed. You may also configure analog or digital 
filters before recording to increase rise and fall times. In no case may 
the mean rise time or mean fall time be greater than 10 seconds.
    (2) If a measurement system fails the criterion in paragraph (e)(1) 
of this section, ensure that signals from the system are updated and 
recorded at a frequency of at least 5 Hz. In no case may the mean rise 
time or mean fall time be greater than 10 seconds.
    (3) If a measurement system fails the criteria in paragraphs (e)(1) 
and (2) of this section, you may use the measurement system only if the 
deficiency does not adversely affect your ability to show compliance 
with the applicable standards in this chapter.
    (f) Transformation time, t50, determination. If you 
choose to determine t50 for purposes of time alignment using 
data generated in paragraph (d)(3) of this section, calculate the mean 
t0-50 and the mean t100-50 from the recorded data. 
Average these two values to determine the final t50 for the 
purposes of time alignment in accordance with Sec.  1065.650(c)(2)(i).
    (g) Optional procedure. Instead of using a three-way valve to switch 
between zero and span gases, you may use

[[Page 113]]

a fast-acting two-way valve to switch sampling between ambient air and 
span gas at the probe inlet. For this alternate procedure, the following 
provisions apply:
    (1) If your probe is sampling from a continuously flowing gas stream 
(e.g., a CVS tunnel), you may adjust the span gas flow rate to be 
different than the sample flow rate.
    (2) If your probe is sampling from a gas stream that is not 
continuously flowing (e.g., a raw exhaust stack), you must adjust the 
span gas flow rate to be less than the sample flow rate so ambient air 
is always being drawn into the probe inlet. This avoids errors 
associated with overflowing span gas out of the probe inlet and drawing 
it back in when sampling ambient air.
    (3) When sampling ambient air or ambient air mixed with span gas, 
all the analyzer readings must be stable within 0.5% of the target gas concentration step size. If any 
analyzer reading is outside the specified range, you must resolve the 
problem and verify that all the analyzer readings meet this 
specification.
    (4) For oxygen analyzers, you may use purified N2 as the 
zero gas and ambient air (plus purified N2 if needed) as the 
reference gas. Perform the verification with seven repeat measurements 
that each consist of stabilizing with purified N2, switching 
to ambient air and observing the analyzer's rise and stabilized reading, 
followed by switching back to purified N2 and observing the 
analyzer's fall and stabilized reading.

[73 FR 59325, Oct. 8, 2008, as amended at 79 FR 23766, Apr. 28, 2014; 88 
FR 4674, Jan. 24, 2023]



Sec.  1065.309  Continuous gas analyzer system-response and updating
-recording verification--for gas analyzers continuously compensated
for other gas species.

    (a) Scope and frequency. This section describes a verification 
procedure for system response and updating-recording frequency for 
continuous gas analyzers that output a single gas species mole fraction 
(i.e., concentration) based on a continuous combination of multiple gas 
species measured with multiple detectors (i.e., gas analyzers 
continuously compensated for other gas species). See Sec.  1065.308 for 
verification procedures that apply to continuous gas analyzers that are 
not continuously compensated for other gas species or that use only one 
detector for gaseous species. Perform this verification to determine the 
system response of the continuous gas analyzer and its sampling system. 
This verification is required for continuous gas analyzers used for 
transient or ramped-modal testing. You need not perform this 
verification for batch gas analyzers or for continuous gas analyzers 
that are used only for discrete-mode testing. For this check we consider 
water vapor a gaseous constituent. This verification does not apply to 
any processing of individual analyzer signals that are time-aligned to 
their t50 times and were verified according to Sec.  
1065.308. For example, this verification does not apply to correction 
for water removed from the sample done in post-processing according to 
Sec.  1065.659 (40 CFR 1066.620 for vehicle testing) and it does not 
apply to NMHC determination from THC and CH4 according to 
Sec.  1065.660. Perform this verification after initial installation 
(i.e., test cell commissioning) and after any modifications to the 
system that would change the system response.
    (b) Measurement principles. This procedure verifies that the 
updating and recording frequencies match the overall system response to 
a rapid change in the value of concentrations at the sample probe. It 
indirectly verifies the time-alignment and uniform response of all the 
continuous gas detectors used to generate a continuously combined/
compensated concentration measurement signal. Gas analyzer systems must 
be optimized such that their overall response to rapid change in 
concentration is updated and recorded at an appropriate frequency to 
prevent loss of information. This test also verifies that the 
measurement system meets a minimum response time. For this procedure, 
ensure that all compensation algorithms and humidity corrections are 
turned on. You may use the results of this test to determine 
transformation time, t50, for the purposes of time alignment 
of continuous data in accordance with Sec.  1065.650(c)(2)(i). You may 
also use an

[[Page 114]]

alternate procedure to determine t50 consistent with good 
engineering judgment. Note that any such procedure for determining 
t50 must account for both transport delay and analyzer 
response time.
    (c) System requirements. Demonstrate that each continuously 
combined/compensated concentration measurement has adequate updating and 
recording frequencies and has a minimum rise time and a minimum fall 
time during a system response to a rapid change in multiple gas 
concentrations, including H2O concentration if H2O 
compensation is applied. You must meet one of the following criteria:
    (1) The product of the mean rise time, t10-90, and the 
frequency at which the system records an updated concentration must be 
at least 5, and the product of the mean fall time, t90-10, 
and the frequency at which the system records an updated concentration 
must be at least 5. If the recording frequency is different than the 
update frequency of the continuously combined/compensated signal, you 
must use the lower of these two frequencies for this verification. This 
criterion makes no assumption regarding the frequency content of changes 
in emission concentrations during emission testing; therefore, it is 
valid for any testing. Also, the mean rise time must be at or below 10 
seconds and the mean fall time must be at or below 10 seconds.
    (2) The frequency at which the system records an updated 
concentration must be at least 5 Hz. This criterion assumes that the 
frequency content of significant changes in emission concentrations 
during emission testing do not exceed 1 Hz. Also, the mean rise time 
must be at or below 10 seconds and the mean fall time must be at or 
below 10 seconds.
    (3) You may use other criteria if we approve them in advance.
    (4) You may meet the overall PEMS verification in Sec.  1065.920 
instead of the verification in this section for field testing with PEMS.
    (d) Procedure. Use the following procedure to verify the response of 
each continuously compensated analyzer (verify the combined signal, not 
each individual continuously combined concentration signal):
    (1) Instrument setup. Follow the analyzer manufacturer's start-up 
and operating instructions. Adjust the measurement system as needed to 
optimize performance. Run this verification with the analyzer operating 
in the same manner you will use for emission testing. If the analyzer 
shares its sampling system with other analyzers, and if gas flow to the 
other analyzers will affect the system response time, then start up and 
operate the other analyzers while running this verification test. You 
may run this verification test on multiple analyzers sharing the same 
sampling system at the same time. If you use any analog or real-time 
digital filters during emission testing, you must operate those filters 
in the same manner during this verification.
    (2) Equipment setup. We recommend using minimal lengths of gas 
transfer lines between all connections and fast-acting three-way valves 
(2 inlets, 1 outlet) to control the flow of zero and blended span gases 
to the sample system's probe inlet or a tee near the outlet of the 
probe. If you inject the gas at a tee near the outlet of the probe, you 
may correct the transformation time, t50, for an estimate of 
the transport time from the probe inlet to the tee. Normally the gas 
flow rate is higher than the sample flow rate and the excess is 
overflowed out the inlet of the probe. If the gas flow rate is lower 
than the sample flow rate, the gas concentrations must be adjusted to 
account for the dilution from ambient air drawn into the probe. We 
recommend you use the final, stabilized analyzer reading as the final 
gas concentration. Select span gases for the species being continuously 
combined, other than H2O. Select concentrations of 
compensating species that will yield concentrations of these species at 
the analyzer inlet that covers the range of concentrations expected 
during testing. You may use binary or multi-gas span gases. You may use 
a gas blending or mixing device to blend span gases. A gas blending or 
mixing device is recommended when blending span gases diluted in 
N2 with span gases diluted in air. You may use a multi-gas 
span gas, such as NO-CO-CO2-C3H8-
CH4, to verify multiple analyzers at the same time. In 
designing your experimental setup,

[[Page 115]]

avoid pressure pulsations due to stopping the flow through the gas 
blending device. The change in gas concentration must be at least 20% of 
the analyzer's range. If H2O correction is applicable, then 
span gases must be humidified before entering the analyzer; however, you 
may not humidify NO2 span gas by passing it through a sealed 
humidification vessel that contains H2O. You must humidify 
NO2 span gas with another moist gas stream. We recommend 
humidifying your NO-CO-CO2-C3H8-
CH4, balance N2, blended gas by bubbling the gas 
mixture that meets the specifications in Sec.  1065.750 through 
distilled H2O in a sealed vessel and then mixing the gas with 
dry NO2 gas, balance purified air, or by using a device that 
introduces distilled H2O as vapor into a controlled span gas 
flow. If the sample does not pass through a dryer during emission 
testing, humidify your span gas to an H2O level at or above 
the maximum expected during emission testing. If the sample passes 
through a dryer during emission testing, it must pass the sample dryer 
verification check in Sec.  1065.342, and you must humidify your span 
gas to an H2O level at or above the level determined in Sec.  
1065.145(e)(2) for that dryer. If you are humidifying span gases without 
NO2, use good engineering judgment to ensure that the wall 
temperatures in the transfer lines, fittings, and valves from the 
humidifying system to the probe are above the dewpoint required for the 
target H2O content. If you are humidifying span gases with 
NO2, use good engineering judgment to ensure that there is no 
condensation in the transfer lines, fittings, or valves from the point 
where humidified gas is mixed with NO2 span gas to the probe. 
We recommend that you design your setup so that the wall temperatures in 
the transfer lines, fittings, and valves from the humidifying system to 
the probe are at least 5 [deg]C above the local sample gas dewpoint. 
Operate the measurement and sample handling system as you do for 
emission testing. Make no modifications to the sample handling system to 
reduce the risk of condensation. Flow humidified gas through the 
sampling system before this check to allow stabilization of the 
measurement system's sampling handling system to occur, as it would for 
an emission test.
    (3) Data collection. (i) Start the flow of zero gas.
    (ii) Allow for stabilization, accounting for transport delays and 
the slowest analyzer's full response.
    (iii) Start recording data. For this verification you must record 
data at a frequency greater than or equal to that of the updating-
recording frequency used during emission testing. You may not use 
interpolation or filtering to alter the recorded values.
    (iv) Switch the flow to allow the blended span gases to flow to the 
analyzer. If you intend to use the data from this test to determine 
t50 for time alignment, record this time as t0.
    (v) Allow for transport delays and the slowest analyzer's full 
response.
    (vi) Switch the flow to allow zero gas to flow to the analyzer. If 
you intend to use the data from this test to determine t50 
for time alignment, record this time as t100.
    (vii) Allow for transport delays and the slowest analyzer's full 
response.
    (viii) Repeat the steps in paragraphs (d)(3)(iv) through (vii) of 
this section to record seven full cycles, ending with zero gas flowing 
to the analyzers.
    (ix) Stop recording.
    (e) Performance evaluations. (1) If you choose to demonstrate 
compliance with paragraph (c)(1) of this section, use the data from 
paragraph (d)(3) of this section to calculate the mean rise time, 
t10-90, and mean fall time, t90-10, for the 
continuously combined signal from each analyzer being verified. You may 
use interpolation between recorded values to determine rise and fall 
times. If the recording frequency used during emission testing is 
different from the analyzer's output update frequency, you must use the 
lower of these two frequencies for this verification. Multiply these 
times (in seconds) by their respective updating-recording frequencies in 
Hz (1/second). The resulting product must be at least 5 for both rise 
time and fall time. If either value is less than 5, increase the 
updating-recording frequency or adjust the flows or design of the 
sampling system to increase the rise time and fall time as needed. You 
may also configure

[[Page 116]]

analog or digital filters before recording to increase rise and fall 
times. In no case may the mean rise time or mean fall time be greater 
than 10 seconds.
    (2) If a measurement system fails the criterion in paragraph (e)(1) 
of this section, ensure that signals from the system are updated and 
recorded at a frequency of at least 5 Hz. In no case may the mean rise 
time or mean fall time be greater than 10 seconds.
    (3) If a measurement system fails the criteria in paragraphs (e)(1) 
and (2) of this section, you may use the measurement system only if the 
deficiency does not adversely affect your ability to show compliance 
with the applicable standards in this chapter.
    (f) Transformation time, t50, determination. If you 
choose to determine t50 for purposes of time alignment using 
data generated in paragraph (d)(3) of this section, calculate the mean 
t0-50 and the mean t100-50 from the recorded data. 
Average these two values to determine the final t50 for the 
purposes of time alignment in accordance with Sec.  1065.650(c)(2)(i).
    (g) Optional procedure. Follow the optional procedures in Sec.  
1065.308(g), noting that you may use compensating gases mixed with 
ambient air for oxygen analyzers.
    (h) Analyzers with H2O compensation sampling downstream of a sample 
dryer. You may omit humidifying the span gas as described in this 
paragraph (h). If an analyzer compensates only for H2O, you 
may apply the requirements of Sec.  1065.308 instead of the requirements 
of this section. You may omit humidifying the span gas if you meet the 
following conditions:
    (1) The analyzer is located downstream of a sample dryer.
    (2) The maximum value for H2O mole fraction downstream of 
the dryer must be less than or equal to 0.010. Verify this during each 
sample dryer verification according to Sec.  1065.342.

[73 FR 59326, Oct. 8, 2008, as amended at 75 FR 23039, Apr. 30, 2010; 79 
FR 23767, Apr. 28, 2014; 86 FR 34541, June 29, 2021; 88 FR 4674, Jan. 
24, 2023]

         Measurement of Engine Parameters and Ambient Conditions



Sec.  1065.310  Torque calibration.

    (a) Scope and frequency. Calibrate all torque-measurement systems 
including dynamometer torque measurement transducers and systems upon 
initial installation and after major maintenance. Use good engineering 
judgment to repeat the calibration. Follow the torque transducer 
manufacturer's instructions for linearizing your torque sensor's output. 
We recommend that you calibrate the torque-measurement system with a 
reference force and a lever arm.
    (b) Recommended procedure to quantify lever-arm length. Quantify the 
lever-arm length, NIST-traceable within 0.5% 
uncertainty. The lever arm's length must be measured from the centerline 
of the dynamometer to the point at which the reference force is 
measured. The lever arm must be perpendicular to gravity (i.e., 
horizontal), and it must be perpendicular to the dynamometer's 
rotational axis. Balance the lever arm's torque or quantify its net 
hanging torque, NIST-traceable within 1% 
uncertainty, and account for it as part of the reference torque.
    (c) Recommended procedure to quantify reference force. We recommend 
dead-weight calibration, but you may use either of the following 
procedures to quantify the reference force, NIST-traceable within 0.5% uncertainty.
    (1) Dead-weight calibration. This technique applies a known force by 
hanging known weights at a known distance along a lever arm. Make sure 
the weights' lever arm is perpendicular to gravity (i.e., horizontal) 
and perpendicular to the dynamometer's rotational axis. Apply at least 
six calibration-weight combinations for each applicable torque-measuring 
range, spacing the weight quantities about equally over the range. 
Oscillate or rotate the dynamometer during calibration to reduce 
frictional static hysteresis. Determine each weight's reference force by 
multiplying its NIST-traceable mass by the local acceleration of Earth's 
gravity, as described in Sec.  1065.630. Calculate the reference torque 
as the weights' reference force multiplied by the lever arm reference 
length.

[[Page 117]]

    (2) Strain gage, load transducer, or proving ring calibration. This 
technique applies force either by hanging weights on a lever arm (these 
weights and their lever arm length are not used as part of the reference 
torque determination) or by operating the dynamometer at different 
torques. Apply at least six force combinations for each applicable 
torque-measuring range, spacing the force quantities about equally over 
the range. Oscillate or rotate the dynamometer during calibration to 
reduce frictional static hysteresis. In this case, the reference torque 
is determined by multiplying the force output from the reference meter 
(such as a strain gage, load transducer, or proving ring) by its 
effective lever-arm length, which you measure from the point where the 
force measurement is made to the dynamometer's rotational axis. Make 
sure you measure this length perpendicular to the reference meter's 
measurement axis and perpendicular to the dynamometer's rotational axis.

[79 FR 23768, Apr. 28, 2014]



Sec.  1065.315  Pressure, temperature, and dewpoint calibration.

    (a) Calibrate instruments for measuring pressure, temperature, and 
dewpoint upon initial installation. Follow the instrument manufacturer's 
instructions and use good engineering judgment to repeat the 
calibration, as follows:
    (1) Pressure. We recommend temperature-compensated, digital-
pneumatic, or deadweight pressure calibrators, with data-logging 
capabilities to minimize transcription errors. We recommend using 
calibration reference quantities that are NIST-traceable within 0.5% uncertainty.
    (2) Temperature. We recommend digital dry-block or stirred-liquid 
temperature calibrators, with data logging capabilities to minimize 
transcription errors. We recommend using calibration reference 
quantities that are NIST-traceable within 0.5% 
uncertainty. You may perform linearity verification for temperature 
measurement systems with thermocouples, RTDs, and thermistors by 
removing the sensor from the system and using a simulator in its place. 
Use a NIST-traceable simulator that is independently calibrated and, as 
appropriate, cold-junction compensated. The simulator uncertainty scaled 
to absolute temperature must be less than 0.5% of Tmax. If 
you use this option, you must use sensors that the supplier states are 
accurate to better than 0.5% of Tmax compared with their 
standard calibration curve.
    (3) Dewpoint. We recommend a minimum of three different temperature-
equilibrated and temperature-monitored calibration salt solutions in 
containers that seal completely around the dewpoint sensor. We recommend 
using calibration reference quantities that are NIST-traceable within 
0.5% uncertainty.
    (b) You may remove system components for off-site calibration. We 
recommend specifying calibration reference quantities that are NIST-
traceable within 0.5% uncertainty.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37305, June 30, 2008; 
75 FR 23040, Apr. 30, 2010; 79 FR 23768, Apr. 28, 2014; 88 FR 4674, Jan. 
24, 2023]

                        Flow-Related Measurements



Sec.  1065.320  Fuel-flow calibration.

    (a) Calibrate fuel-flow meters upon initial installation. Follow the 
instrument manufacturer's instructions and use good engineering judgment 
to repeat the calibration.
    (b) [Reserved]
    (c) You may remove system components for off-site calibration. When 
installing a flow meter with an off-site calibration, we recommend that 
you consider the effects of the tubing configuration upstream and 
downstream of the flow meter. We recommend specifying calibration 
reference quantities that are NIST-traceable within 0.5% uncertainty.

[70 FR 40516, July 13, 2005, as amended at 86 FR 34541, June 29, 2021; 
88 FR 4674, Jan. 24. 2023]



Sec.  1065.325  Intake-flow calibration.

    (a) Calibrate intake-air flow meters upon initial installation. 
Follow the instrument manufacturer's instructions and use good 
engineering judgment to repeat the calibration. We recommend using a 
calibration subsonic venturi, ultrasonic flow meter or laminar flow

[[Page 118]]

element. We recommend using calibration reference quantities that are 
NIST-traceable within 0.5% uncertainty.
    (b) You may remove system components for off-site calibration. When 
installing a flow meter with an off-site calibration, we recommend that 
you consider the effects of the tubing configuration upstream and 
downstream of the flow meter. We recommend specifying calibration 
reference quantities that are NIST-traceable within 0.5% uncertainty.
    (c) If you use a subsonic venturi or ultrasonic flow meter for 
intake flow measurement, we recommend that you calibrate it as described 
in Sec.  1065.340.

[70 FR 40516, July 13, 2005, as amended at 88 FR 4675, Jan. 24, 2023]



Sec.  1065.330  Exhaust-flow calibration.

    (a) Calibrate exhaust-flow meters upon initial installation. Follow 
the instrument manufacturer's instructions and use good engineering 
judgment to repeat the calibration. We recommend that you use a 
calibration subsonic venturi or ultrasonic flow meter and simulate 
exhaust temperatures by incorporating a heat exchanger between the 
calibration meter and the exhaust-flow meter. If you can demonstrate 
that the flow meter to be calibrated is insensitive to exhaust 
temperatures, you may use other reference meters such as laminar flow 
elements, which are not commonly designed to withstand typical raw 
exhaust temperatures. We recommend using calibration reference 
quantities that are NIST-traceable within 0.5% 
uncertainty.
    (b) You may remove system components for off-site calibration. When 
installing a flow meter with an off-site calibration, we recommend that 
you consider the effects of the tubing configuration upstream and 
downstream of the flow meter. We recommend specifying calibration 
reference quantities that are NIST-traceable within 0.5% uncertainty.
    (c) If you use a subsonic venturi or ultrasonic flow meter for raw 
exhaust flow measurement, we recommend that you calibrate it as 
described in Sec.  1065.340.

[70 FR 40516, July 13, 2005, as amended at 88 FR 4675, Jan. 24, 2023]



Sec.  1065.340  Diluted exhaust flow (CVS) calibration.

    (a) Overview. This section describes how to calibrate flow meters 
for diluted exhaust constant-volume sampling (CVS) systems.
    (b) Scope and frequency. Perform this calibration while the flow 
meter is installed in its permanent position, except as allowed in 
paragraph (c) of this section. Perform this calibration after you change 
any part of the flow configuration upstream or downstream of the flow 
meter that may affect the flow-meter calibration. Perform this 
calibration upon initial CVS installation and whenever corrective action 
does not resolve a failure to meet the diluted exhaust flow verification 
(i.e., propane check) in Sec.  1065.341.
    (c) Ex-situ CFV and SSV calibration. You may remove a CFV or SSV 
from its permanent position for calibration as long as it meets the 
following requirements when installed in the CVS:
    (1) Upon installation of the CFV or SSV into the CVS, use good 
engineering judgment to verify that you have not introduced any leaks 
between the CVS inlet and the venturi.
    (2) After ex-situ venturi calibration, you must verify all venturi 
flow combinations for CFVs or at minimum of 10 flow points for an SSV 
using the propane check as described in Sec.  1065.341. Your propane 
check result for each venturi flow point may not exceed the tolerance in 
Sec.  1065.341(f)(5).
    (3) To verify your ex-situ calibration for a CVS with more than a 
single CFV, perform the following check to verify that there are no flow 
meter entrance effects that can prevent you from passing this 
verification.
    (i) Use a constant flow device like a CFO kit to deliver a constant 
flow of propane to the dilution tunnel.
    (ii) Measure hydrocarbon concentrations at a minimum of 10 separate 
flow rates for an SSV flow meter, or at all possible flow combinations 
for a CFV flow meter, while keeping the flow of

[[Page 119]]

propane constant. We recommend selecting CVS flow rates in a random 
order.
    (iii) Measure the concentration of hydrocarbon background in the 
dilution air at the beginning and end of this test. Subtract the average 
background concentration from each measurement at each flow point before 
performing the regression analysis in paragraph (c)(3)(iv) of this 
section.
    (iv) Perform a power regression using all the paired values of flow 
rate and corrected concentration to obtain a relationship in the form of 
y = a [middot] x \b\. Use concentration as the independent variable and 
flow rate as the dependent variable. For each data point, calculate the 
difference between the measured flow rate and the value represented by 
the curve fit. The difference at each point must be less than 1% of the appropriate regression value. The value of b 
must be between -1.005 and -0.995. If your results do not meet these 
limits, take corrective action consistent with Sec.  1065.341(a).
    (d) Reference flow meter. Calibrate a CVS flow meter using a 
reference flow meter such as a subsonic venturi flow meter, a long-
radius ASME/NIST flow nozzle, a smooth approach orifice, a laminar flow 
element, a set of critical flow venturis, or an ultrasonic flow meter. 
Use a reference flow meter that reports quantities that are NIST-
traceable within 1% uncertainty. Use this 
reference flow meter's response to flow as the reference value for CVS 
flow-meter calibration.
    (e) Configuration. Calibrate the system with any upstream screens or 
other restrictions that will be used during testing and that could 
affect the flow ahead of the CVS flow meter, using good engineering 
judgment to minimize the effect on the flow distribution. You may not 
use any upstream screen or other restriction that could affect the flow 
ahead of the reference flow meter, unless the flow meter has been 
calibrated with such a restriction. In the case of a free standing SSV 
reference flow meter, you may not have any upstream screens.
    (f) PDP calibration. Calibrate a positive-displacement pump (PDP) to 
determine a flow-versus-PDP speed equation that accounts for flow 
leakage across sealing surfaces in the PDP as a function of PDP inlet 
pressure. Determine unique equation coefficients for each speed at which 
you operate the PDP. Calibrate a PDP flow meter as follows:
    (1) Connect the system as shown in Figure 1 of this section.
    (2) Leaks between the calibration flow meter and the PDP must be 
less than 0.3% of the total flow at the lowest calibrated flow point; 
for example, at the highest restriction and lowest PDP-speed point.
    (3) While the PDP operates, maintain a constant temperature at the 
PDP inlet within 2% of the mean absolute inlet 
temperature, Tin.
    (4) Set the PDP speed to the first speed point at which you intend 
to calibrate.
    (5) Set the variable restrictor to its wide-open position.
    (6) Operate the PDP for at least 3 min to stabilize the system. 
Continue operating the PDP and record the mean values of at least 30 
seconds of sampled data of each of the following quantities:
    (i) The mean flow rate of the reference flow meter, 
niref. This may include several measurements of different 
quantities, such as reference meter pressures and temperatures, for 
calculating niref.
    (ii) The mean temperature at the PDP inlet, Tin.
    (iii) The mean static absolute pressure at the PDP inlet, 
pin.
    (iv) The mean static absolute pressure at the PDP outlet, 
pout.
    (v) The mean PDP speed, fnPDP.
    (7) Incrementally close the restrictor valve to decrease the 
absolute pressure at the inlet to the PDP, pin.
    (8) Repeat the steps in paragraphs (e)(6) and (7) of this section to 
record data at a minimum of six restrictor positions ranging from the 
wide open restrictor position to the minimum expected pressure at the 
PDP inlet or the maximum expected differential (outlet minus inlet) 
pressure across the PDP during testing.
    (9) Calibrate the PDP by using the collected data and the equations 
in Sec.  1065.640.
    (10) Repeat the steps in paragraphs (e)(6) through (9) of this 
section for

[[Page 120]]

each speed at which you operate the PDP.
    (11) Use the equations in Sec.  1065.642 to determine the PDP flow 
equation for emission testing.
    (12) Verify the calibration by performing a CVS verification (i.e., 
propane check) as described in Sec.  1065.341.
    (13) During emission testing ensure that the PDP is not operated 
either below the lowest inlet pressure point or above the highest 
differential pressure point in the calibration data.
    (g) SSV calibration. Calibrate a subsonic venturi (SSV) to determine 
its calibration coefficient, Cd, for the expected range of 
inlet pressures. Calibrate an SSV flow meter as follows:
    (1) Connect the system as shown in Figure 1 of this section.
    (2) Verify that any leaks between the calibration flow meter and the 
SSV are less than 0.3% of the total flow at the highest restriction.
    (3) Start the blower downstream of the SSV.
    (4) While the SSV operates, maintain a constant temperature at the 
SSV inlet within 2% of the mean absolute inlet 
temperature, Tin.
    (5) Set the variable restrictor or variable-speed blower to a flow 
rate greater than the greatest flow rate expected during testing. You 
may not extrapolate flow rates beyond calibrated values, so we recommend 
that you make sure the Reynolds number, Re#, at the SSV 
throat at the greatest calibrated flow rate is greater than the maximum 
Re# expected during testing.
    (6) Operate the SSV for at least 3 min to stabilize the system. 
Continue operating the SSV and record the mean of at least 30 seconds of 
sampled data of each of the following quantities:
    (i) The mean flow rate of the reference flow meter niref. 
This may include several measurements of different quantities for 
calculating niref, such as reference meter pressures and 
temperatures.
    (ii) Optionally, the mean dewpoint of the calibration 
air,Tdew. See Sec.  1065.640 for permissible assumptions.
    (iii) The mean temperature at the venturi inlet,Tin.
    (iv) The mean static absolute pressure at the venturi inlet, 
Pin.
    (v) The mean static differential pressure between the static 
pressure at the venturi inlet and the static pressure at the venturi 
throat, [Delta]PSSV.
    (7) Incrementally close the restrictor valve or decrease the blower 
speed to decrease the flow rate.
    (8) Repeat the steps in paragraphs (g)(6) and (7) of this section to 
record data at a minimum of ten flow rates.
    (9) Determine an equation to quantify Cd as a function of 
Re# by using the collected data and the equations in Sec.  
1065.640. Section 1065.640 also includes statistical criteria for 
validating the Cd versus Re# equation.
    (10) Verify the calibration by performing a CVS verification (i.e., 
propane check) as described in Sec.  1065.341 using the new 
Cd versus Re# equation.
    (11) Use the SSV only between the minimum and maximum calibrated 
Re#. If you want to use the SSV at a lower or higher 
Re#, you must recalibrate the SSV.
    (12) Use the equations in Sec.  1065.642 to determine SSV flow 
during a test.
    (h) CFV calibration. Calibrate a critical-flow venturi (CFV) to 
verify its discharge coefficient, Cd, up to the highest 
expected pressure ratio, r, according to Sec.  1065.640. Calibrate a CFV 
flow meter as follows:
    (1) Connect the system as shown in Figure 1 of this section.
    (2) Verify that any leaks between the calibration flow meter and the 
CFV are less than 0.3% of the total flow at the highest restriction.
    (3) Start the blower downstream of the CFV.
    (4) While the CFV operates, maintain a constant temperature at the 
CFV inlet within 2% of the mean absolute inlet 
temperature, Tin.
    (5) Set the variable restrictor to its wide-open position. Instead 
of a variable restrictor, you may alternately vary the pressure 
downstream of the CFV by varying blower speed or by introducing a 
controlled leak. Note that some blowers have limitations on nonloaded 
conditions.
    (6) Operate the CFV for at least 3 min to stabilize the system. 
Continue operating the CFV and record the mean values of at least 30 
seconds of sampled data of each of the following quantities:

[[Page 121]]

    (i) The mean flow rate of the reference flow meter, 
niref. This may include several measurements of different 
quantities, such as reference meter pressures and temperatures, for 
calculating niref.
    (ii) The mean dewpoint of the calibration air,Tdew. See 
Sec.  1065.640 for permissible assumptions during emission measurements.
    (iii) The mean temperature at the venturi inlet,Tin.
    (iv) The mean static absolute pressure at the venturi inlet, 
Pin.
    (v) The mean static differential pressure between the CFV inlet and 
the CFV outlet, [Delta]PCFV.
    (7) Incrementally close the restrictor valve or decrease the 
downstream pressure to decrease the differential pressure across the 
CFV, [Delta]pCFV.
    (8) Repeat the steps in paragraphs (f)(6) and (7) of this section to 
record mean data at a minimum of ten restrictor positions, such that you 
test the fullest practical range of [Delta]PCFV expected 
during testing. We do not require that you remove calibration components 
or CVS components to calibrate at the lowest possible restrictions.
    (9) Determine Cd and the highest allowable pressure 
ratio, r, according to Sec.  1065.640.
    (10) Use Cd to determine CFV flow during an emission 
test. Do not use the CFV above the highest allowed r, as determined in 
Sec.  1065.640.
    (11) Verify the calibration by performing a CVS verification (i.e., 
propane check) as described in Sec.  1065.341.
    (12) If your CVS is configured to operate more than one CFV at a 
time in parallel, calibrate your CVS by one of the following:
    (i) Calibrate every combination of CFVs according to this section 
and Sec.  1065.640. Refer to Sec.  1065.642 for instructions on 
calculating flow rates for this option.
    (ii) Calibrate each CFV according to this section and Sec.  
1065.640. Refer to Sec.  1065.642 for instructions on calculating flow 
rates for this option.
    (i) Ultrasonic flow meter calibration. [Reserved]


[[Page 122]]

[GRAPHIC] [TIFF OMITTED] TR25OC16.159


[[Page 123]]



[70 FR 40516, July 13, 2005, as amended at 73 FR 37305, June 30, 2008; 
75 FR 68463, Nov. 8, 2010; 76 FR 57445, Sept. 15, 2011; 81 FR 74165, 
Oct. 25, 2016]



Sec.  1065.341  CVS and PFD flow verification (propane check).

    This section describes two optional methods, using propane as a 
tracer gas, to verify CVS and PFD flow streams. You may use good 
engineering judgment and safe practices to use other tracer gases, such 
as CO2 or CO. The first method, described in paragraphs (a) 
through (e) of this section, applies for the CVS diluted exhaust flow 
measurement system. The first method may also apply for other single-
flow measurement systems as described in Table 2 of Sec.  1065.307. 
Paragraph (g) of this section describes a second method you may use to 
verify flow measurements in a PFD for determining the PFD dilution 
ratio.
    (a) A propane check uses either a reference mass or a reference flow 
rate of C3H8 as a tracer gas in a CVS. Note that 
if you use a reference flow rate, account for any non-ideal gas behavior 
of C3H8 in the reference flow meter. Refer to 
Sec. Sec.  1065.640 and 1065.642, which describe how to calibrate and 
use certain flow meters. Do not use any ideal gas assumptions in 
Sec. Sec.  1065.640 and 1065.642. The propane check compares the 
calculated mass of injected C3H8 using HC 
measurements and CVS flow rate measurements with the reference value.
    (b) Prepare for the propane check as follows:
    (1) If you use a reference mass of C3H8 
instead of a reference flow rate, obtain a cylinder charged with 
C3H8. Determine the reference cylinder's mass of 
C3H8 within 0.5% of the 
amount of C3H8 that you expect to use. You may 
substitute a C3H8 analytical gas mixture (i.e., a 
prediluted tracer gas) for pure C3H8. This would 
be most appropriate for lower flow rates. The analytical gas mixture 
must meet the specifications in Sec.  1065.750(a)(3).
    (2) Select appropriate flow rates for the CVS and 
C3H8.
    (3) Select a C3H8 injection port in the CVS. 
Select the port location to be as close as practical to the location 
where you introduce engine exhaust into the CVS, or at some point in the 
laboratory exhaust tubing upstream of this location. Connect the 
C3H8 cylinder to the injection system.
    (4) Operate and stabilize the CVS.
    (5) Preheat or pre-cool any heat exchangers in the sampling system.
    (6) Allow heated and cooled components such as sample lines, 
filters, chillers, and pumps to stabilize at operating temperature.
    (7) You may purge the HC sampling system during stabilization.
    (8) If applicable, perform a vacuum side leak verification of the HC 
sampling system as described in Sec.  1065.345.
    (9) You may also conduct any other calibrations or verifications on 
equipment or analyzers.
    (c) If you performed the vacuum-side leak verification of the HC 
sampling system as described in paragraph (b)(8) of this section, you 
may use the HC contamination procedure in Sec.  1065.520(f) to verify HC 
contamination. Otherwise, zero, span, and verify contamination of the HC 
sampling system, as follows:
    (1) Select the lowest HC analyzer range that can measure the 
C3H8 concentration expected for the CVS and 
C3H8 flow rates.
    (2) Zero the HC analyzer using zero air introduced at the analyzer 
port.
    (3) Span the HC analyzer using C3H8 span gas 
introduced at the analyzer port.
    (4) Overflow zero air at the HC probe inlet or into a tee near the 
outlet of the probe.
    (5) Measure the stable HC concentration of the HC sampling system as 
overflow zero air flows. For batch HC measurement, fill the batch 
container (such as a bag) and measure the HC overflow concentration.
    (6) If the overflow HC concentration exceeds 2 [micro]mol/mol, do 
not proceed until contamination is eliminated. Determine the source of 
the contamination and take corrective action, such as cleaning the 
system or replacing contaminated portions.
    (7) When the overflow HC concentration does not exceed 2 [micro]mol/
mol, record this value as xTHCinit and use it to correct for 
HC contamination as described in Sec.  1065.660.
    (d) Perform the propane check as follows:

[[Page 124]]

    (1) For batch HC sampling, connect clean storage media, such as 
evacuated bags.
    (2) Operate HC measurement instruments according to the instrument 
manufacturer's instructions.
    (3) If you will correct for dilution air background concentrations 
of HC, measure and record background HC in the dilution air.
    (4) Zero any integrating devices.
    (5) Begin sampling, and start any flow integrators.
    (6) Release the contents of the C3H8 reference 
cylinder at the rate you selected. If you use a reference flow rate of 
C3H8, start integrating this flow rate.
    (7) Continue to release the cylinder's contents until at least 
enough C3H8 has been released to ensure accurate 
quantification of the reference C3H8 and the 
measured C3H8.
    (8) Shut off the C3H8 reference cylinder and 
continue sampling until you have accounted for time delays due to sample 
transport and analyzer response.
    (9) Stop sampling and stop any integrators.
    (e) Perform post-test procedure as follows:
    (1) If you used batch sampling, analyze batch samples as soon as 
practical.
    (2) After analyzing HC, correct for contamination and background.
    (3) Calculate total C3H8 mass based on your 
CVS and HC data as described in Sec.  1065.650 (40 CFR 1066.605 for 
vehicle testing) and Sec.  1065.660, using the molar mass of 
C3H8, MC3H8, instead of the effective 
molar mass of HC, MHC.
    (4) If you use a reference mass, determine the cylinder's propane 
mass within 0.5% and determine the 
C3H8 reference mass by subtracting the empty 
cylinder propane mass from the full cylinder propane mass.
    (5) Subtract the reference C3H8 mass from the 
calculated mass. If this difference is within 2% 
of the reference mass, the CVS passes this verification. If not, take 
corrective action as described in paragraph (f) of this section.
    (f) A failed propane check might indicate one or more problems 
requiring corrective action, as follows:

  Table 1 of Sec.   1065.341--Troubleshooting Guide for Propane Checks
------------------------------------------------------------------------
                Problem                   Recommended corrective action
------------------------------------------------------------------------
Incorrect analyzer calibration.........  Recalibrate, repair, or replace
                                          the FID analyzer.
Leaks..................................  Inspect CVS tunnel,
                                          connections, fasteners, and HC
                                          sampling system. Repair or
                                          replace components.
Poor mixing............................  Perform the verification as
                                          described in this section
                                          while traversing a sampling
                                          probe across the tunnel's
                                          diameter, vertically and
                                          horizontally. If the analyzer
                                          response indicates any
                                          deviation exceeding 2% of the mean
                                          measured concentration,
                                          consider operating the CVS at
                                          a higher flow rate or
                                          installing a mixing plate or
                                          orifice to improve mixing.
Hydrocarbon contamination in the sample  Perform the hydrocarbon-
 system.                                  contamination verification as
                                          described in Sec.   1065.520.
Change in CVS calibration..............  Perform a calibration of the
                                          CVS flow meter as described in
                                          Sec.   1065.340.
Flow meter entrance effects............  Inspect the CVS tunnel to
                                          determine whether the entrance
                                          effects from the piping
                                          configuration upstream of the
                                          flow meter adversely affect
                                          the flow measurement.
Other problems with the CVS or sampling  Inspect the CVS system and
 verification hardware or software.       related verification hardware,
                                          and software for
                                          discrepancies.
------------------------------------------------------------------------

    (g) You may verify flow measurements in a PFD (usually dilution air 
and diluted exhaust streams) for determining the dilution ratio in the 
PFD using the following method:
    (1) Configure the HC sampling system to extract a sample from the 
PFD's diluted exhaust stream (such as near a PM filter). If the absolute 
pressure at this location is too low to extract an HC sample, you may 
sample HC from the PFD's pump exhaust. Use caution when sampling from 
pump exhaust because an otherwise acceptable pump leak downstream of a 
PFD diluted exhaust flow meter will cause a false failure of the propane 
check.
    (2) Perform the propane check described in paragraphs (b), (c), and 
(d) of this section, but sample HC from the

[[Page 125]]

PFD's diluted exhaust stream. Inject the propane in the same exhaust 
stream that the PFD is sampling from (either CVS or raw exhaust stack).
    (3) Calculate C3H8 mass, taking into account 
the dilution from the PFD.
    (4) Subtract the reference C3H8 mass from the 
calculated mass. If this difference is within 2% 
of the reference mass, all PFD flow measurements for determining PFD 
dilution ratio pass this verification. If not, take corrective action as 
described in paragraph (f) of this section. For PFDs sampling only for 
PM, the allowed difference is 5%.
    (h) Table 2 of Sec.  1065.307 describes optional verification 
procedures you may perform instead of linearity verification for certain 
flow-measurement systems. Performing carbon balance error verification 
also replaces any required propane checks.

[86 FR 34541, June 29, 2021, as amended at 88 FR 4675, Jan. 24, 2023]



Sec.  1065.342  Sample dryer verification.

    (a) Scope and frequency. If you use a sample dryer as allowed in 
Sec.  1065.145(e)(2) to remove water from the sample gas, verify the 
performance upon installation, after major maintenance, for thermal 
chiller. For osmotic membrane dryers, verify the performance upon 
installation, after major maintenance, and within 35 days of testing.
    (b) Measurement principles. Water can inhibit an analyzer's ability 
to properly measure the exhaust component of interest and thus is 
sometimes removed before the sample gas reaches the analyzer. For 
example water can negatively interfere with a CLD's NOX 
response through collisional quenching and can positively interfere with 
an NDIR analyzer by causing a response similar to CO.
    (c) System requirements. The sample dryer must meet the 
specifications as determined in Sec.  1065.145(e)(2) for dewpoint, 
Tdew, and absolute pressure, ptotal, downstream of 
the osmotic-membrane dryer or thermal chiller.
    (d) Sample dryer verification procedure. Use the following method to 
determine sample dryer performance. Run this verification with the dryer 
and associated sampling system operating in the same manner you will use 
for emission testing (including operation of sample pumps). You may run 
this verification test on multiple sample dryers sharing the same 
sampling system at the same time. You may run this verification on the 
sample dryer alone, but you must use the maximum gas flow rate expected 
during testing. You may use good engineering judgment to develop a 
different protocol.
    (1) Use PTFE or stainless steel tubing to make necessary 
connections.
    (2) Humidify room air, purified N2, or purified air by 
bubbling it through distilled H2O in a sealed vessel or use a 
device that injects distilled H2O as vapor into a controlled 
gas flow to humidify the gas to the highest sample H2O 
content that you estimate during emission sampling.
    (3) Introduce the humidified gas upstream of the sample dryer. You 
may disconnect the transfer line from the probe and introduce the 
humidified gas at the inlet of the transfer line of the sample system 
used during testing. You may use the sample pumps in the sample system 
to draw gas through the vessel.
    (4) Maintain the sample lines, fittings, and valves from the 
location where the humidified gas water content is measured to the inlet 
of the sampling system at a temperature at least 5 [deg]C above the 
local humidified gas dewpoint. For dryers used in NOX sample 
systems, verify the sample system components used in this verification 
prevent aqueous condensation as required in Sec.  1065.145(d)(1)(i). We 
recommend that the sample system components be maintained at least 5 
[deg]C above the local humidified gas dewpoint to prevent aqueous 
condensation.
    (5) Measure the humidified gas dewpoint, Tdew, and 
absolute pressure, ptotal, as close as possible to the inlet 
of the sample dryer or inlet of the sample system to verify the water 
content is at least as high as the highest value that you estimated 
during emission sampling. You may verify the water content based on any 
humidity parameter (e.g. mole fraction water, local dewpoint, or 
absolute humidity).
    (6) Measure the humidified gas dewpoint, Tdew, and 
absolute pressure, ptotal, as close as possible to the outlet 
of the

[[Page 126]]

sample dryer. Note that the dewpoint changes with absolute pressure. If 
the dewpoint at the sample dryer outlet is measured at a different 
pressure, then this reading must be corrected to the dewpoint at the 
sample dryer absolute pressure, ptotal.
    (7) The sample dryer meets the verification if the dewpoint at the 
sample dryer pressure as measured in paragraph (d)(6) of this section is 
less than the dewpoint corresponding to the sample dryer specifications 
as determined in Sec.  1065.145(e)(2) plus 2 [deg]C or if the mole 
fraction of water as measured in (d)(6) is less than the corresponding 
sample dryer specifications plus 0.002 mol/mol.
    (e) Alternate sample dryer verification procedure. The following 
method may be used in place of the sample dryer verification procedure 
in (d) of this section. If you use a humidity sensor for continuous 
monitoring of dewpoint at the sample dryer outlet you may skip the 
performance check in Sec.  1065.342(d), but you must make sure that the 
dryer outlet humidity is at or below the minimum value used for quench, 
interference, and compensation checks.

[73 FR 37307, June 30, 2008, as amended at 73 FR 59328, Oct. 8, 2008; 75 
FR 23040, Apr. 30, 2010; 86 FR 34543, June 29, 2021]



Sec.  1065.345  Vacuum-side leak verification.

    (a) Scope and frequency. Verify that there are no significant 
vacuum-side leaks using one of the leak tests described in this section. 
For laboratory testing, perform the vacuum-side leak verification upon 
initial sampling system installation, within 8 hours before the start of 
the first test interval of each duty-cycle sequence, and after 
maintenance such as pre-filter changes. For field testing, perform the 
vacuum-side leak verification after each installation of the sampling 
system on the vehicle, prior to the start of the field test, and after 
maintenance such as pre-filter changes. This verification does not apply 
to any full-flow portion of a CVS dilution system.
    (b) Measurement principles. A leak may be detected either by 
measuring a small amount of flow when there should be zero flow, or by 
detecting the dilution of a known concentration of span gas when it 
flows through the vacuum side of a sampling system.
    (c) Low-flow leak test. Test a sampling system for low-flow leaks as 
follows:
    (1) Seal the probe end of the system by taking one of the following 
steps:
    (i) Cap or plug the end of the sample probe.
    (ii) Disconnect the transfer line at the probe and cap or plug the 
transfer line.
    (iii) Close a leak-tight valve located in the sample transfer line 
within 92 cm of the probe.
    (2) Operate all vacuum pumps. After stabilizing, verify that the 
flow through the vacuum-side of the sampling system is less than 0.5% of 
the system's normal in-use flow rate. You may estimate typical analyzer 
and bypass flows as an approximation of the system's normal in-use flow 
rate.
    (d) Dilution-of-span-gas leak test. You may use any gas analyzer for 
this test. If you use a FID for this test, correct for any HC 
contamination in the sampling system according to Sec.  1065.660. If you 
use an O2 analyzer described in Sec.  1065.280 for this test, 
you may use purified N2 to detect a leak. To avoid misleading 
results from this test, we recommend using only analyzers that have a 
repeatability of 0.5% or better at the reference gas concentration used 
for this test. Perform a vacuum-side leak test as follows:
    (1) Prepare a gas analyzer as you would for emission testing.
    (2) Supply reference gas to the analyzer span port and record the 
measured value.
    (3) Route overflow reference gas to the inlet of the sample probe or 
at a tee fitting in the transfer line near the exit of the probe. You 
may use a valve upstream of the overflow fitting to prevent overflow of 
reference gas out of the inlet of the probe, but you must then provide 
an overflow vent in the overflow supply line.
    (4) Verify that the measured overflow reference gas concentration is 
within 0.5% of the concentration measured in 
paragraph (d)(2) of this section. A measured value lower than expected 
indicates a leak, but a value higher than expected may indicate a 
problem with the reference gas or the analyzer itself.

[[Page 127]]

A measured value higher than expected does not indicate a leak.
    (e) Vacuum-decay leak test. To perform this test you must apply a 
vacuum to the vacuum-side volume of your sampling system and then 
observe the leak rate of your system as a decay in the applied vacuum. 
To perform this test you must know the vacuum-side volume of your 
sampling system to within 10% of its true volume. 
For this test you must also use measurement instruments that meet the 
specifications of subpart C of this part and of this subpart D. Perform 
a vacuum-decay leak test as follows:
    (1) Seal the probe end of the system as close to the probe opening 
as possible by taking one of the following steps:
    (i) Cap or plug the end of the sample probe.
    (ii) Disconnect the transfer line at the probe and cap or plug the 
transfer line.
    (iii) Close a leak-tight valve located in the sample transfer line 
within 92 cm of the probe.
    (2) Operate all vacuum pumps. Draw a vacuum that is representative 
of normal operating conditions. In the case of sample bags, we recommend 
that you repeat your normal sample bag pump-down procedure twice to 
minimize any trapped volumes.
    (3) Turn off the sample pumps and seal the system. Measure and 
record the absolute pressure of the trapped gas and optionally the 
system absolute temperature. Wait long enough for any transients to 
settle and long enough for a leak at 0.5% to have caused a pressure 
change of at least 10 times the resolution of the pressure transducer, 
then again record the pressure and optionally temperature.
    (4) Calculate the leak flow rate based on an assumed value of zero 
for pumped-down bag volumes and based on known values for the sample 
system volume, the initial and final pressures, optional temperatures, 
and elapsed time. Using the calculations specified in Sec.  1065.644, 
verify that the vacuum-decay leak flow rate is less than 0.5% of the 
system's normal in-use flow rate.

[73 FR 37307, June 30, 2008, as amended at 73 FR 59328, Oct. 8, 2008; 75 
FR 23040, Apr. 30, 2010; 81 FR 74167, Oct. 25, 2016; 88 FR 4675, Jan. 
24, 2023]

                   CO and CO2 Measurements



Sec.  1065.350  H2O interference verification for
CO2 NDIR analyzers.

    (a) Scope and frequency. If you measure CO2 using an NDIR 
analyzer, verify the amount of H2O interference after initial 
analyzer installation and after major maintenance.
    (b) Measurement principles. H2O can interfere with an 
NDIR analyzer's response to CO2.
    If the NDIR analyzer uses compensation algorithms that utilize 
measurements of other gases to meet this interference verification, 
simultaneously conduct these other measurements to test the compensation 
algorithms during the analyzer interference verification.
    (c) System requirements. A CO2 NDIR analyzer must have an 
H2O interference that is within (0.0 0.4) mmol/mol, though we strongly recommend a lower 
interference that is within (0.0 0.2) mmol/mol.
    (d) Procedure. Perform the interference verification as follows:
    (1) Start, operate, zero, and span the CO2 NDIR analyzer 
as you would before an emission test. If the sample is passed through a 
dryer during emission testing, you may run this verification test with 
the dryer if it meets the requirements of Sec.  1065.342. Operate the 
dryer at the same conditions as you will for an emission test. You may 
also run this verification test without the sample dryer.
    (2) Create a humidified test gas by bubbling zero gas that meets the 
specifications in Sec.  1065.750 through distilled H2O in a 
sealed vessel or use a device that introduces distilled H2O 
as vapor into a controlled gas flow. If the sample does not pass through 
a dryer during emission testing, humidify your test gas to an 
H2O level at or above the maximum expected during emission 
testing. If the sample passes through a dryer during emission testing, 
you

[[Page 128]]

must humidify your test gas to an H2O level at or above the 
level determined in Sec.  1065.145(e)(2) for that dryer.
    (3) Introduce the humidified test gas into the sample system. You 
may introduce it downstream of any sample dryer, if one is used during 
testing.
    (4) If the sample is not passed through a dryer during this 
verification test, measure the H2O mole fraction, 
xH2O, of the humidified test gas, as close as possible to the 
inlet of the analyzer. For example, measure dewpoint, Tdew, 
and absolute pressure, ptotal, to calculate xH2O. 
Verify that the H2O content meets the requirement in 
paragraph (d)(2) of this section. If the sample is passed through a 
dryer during this verification test, you must verify that the 
H2O content of the humidified test gas downstream of the 
vessel meets the requirement in paragraph (d)(2) of this section based 
on either direct measurement of the H2O content (e.g., 
dewpoint and pressure) or an estimate based on the vessel pressure and 
temperature. Use good engineering judgment to estimate the 
H2O content. For example, you may use previous direct 
measurements of H2O content to verify the vessel's level of 
saturation.
    (5) If a sample dryer is not used in this verification test, use 
good engineering judgment to prevent condensation in the transfer lines, 
fittings, or valves from the point where xH2O is measured to 
the analyzer. We recommend that you design your system so the wall 
temperatures in the transfer lines, fittings, and valves from the point 
where xH2O is measured to the analyzer are at least 5 [deg]C 
above the local sample gas dewpoint.
    (6) Allow time for the analyzer response to stabilize. Stabilization 
time may include time to purge the transfer line and to account for 
analyzer response.
    (7) While the analyzer measures the sample's concentration, record 
30 seconds of sampled data. Calculate the arithmetic mean of this data. 
The analyzer meets the interference verification if this value is within 
(0.0 0.4) mmol/mol.
    (e) Exceptions. The following exceptions apply:
    (1) You may omit this verification if you can show by engineering 
analysis that for your CO2 sampling system and your emission-
calculation procedures, the H2O interference for your 
CO2 NDIR analyzer always affects your brake-specific emission 
results within 0.5% of each of the applicable 
standards in this chapter. This specification also applies for vehicle 
testing, except that it relates to emission results in g/mile or g/
kilometer.
    (2) You may use a CO2 NDIR analyzer that you determine 
does not meet this verification, as long as you try to correct the 
problem and the measurement deficiency does not adversely affect your 
ability to show that engines comply with all applicable emission 
standards.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37308, June 30, 2008; 
73 FR 59328, Oct. 8, 2008; 75 FR 23040, Apr. 30, 2010; 76 FR 57447, 
Sept. 15, 2011; 79 FR 23768, Apr. 28, 2014; 86 FR 34543, June 29, 2021; 
88 FR 4675, Jan. 24, 2023]



Sec.  1065.355  H2O and CO2 interference 
verification for CO NDIR analyzers.

    (a) Scope and frequency. If you measure CO using an NDIR analyzer, 
verify the amount of H2O and CO2 interference 
after initial analyzer installation and after major maintenance.
    (b) Measurement principles. H2O and CO2 can 
positively interfere with an NDIR analyzer by causing a response similar 
to CO. If the NDIR analyzer uses compensation algorithms that utilize 
measurements of other gases to meet this interference verification, 
simultaneously conduct these other measurements to test the compensation 
algorithms during the analyzer interference verification.
    (c) System requirements. A CO NDIR analyzer must have combined 
H2O and CO2 interference that is within 2 % of the flow-weighted mean concentration of CO 
expected at the standard, though we strongly recommend a lower 
interference that is within 1%.
    (d) Procedure. Perform the interference verification as follows:
    (1) Start, operate, zero, and span the CO NDIR analyzer as you would 
before an emission test. If the sample is passed through a dryer during 
emission testing, you may run this verification

[[Page 129]]

test with the dryer if it meets the requirements of Sec.  1065.342. 
Operate the dryer at the same conditions as you will for an emission 
test. You may also run this verification test without the sample dryer.
    (2) Create a humidified CO2 test gas by bubbling a 
CO2 span gas that meets the specifications in Sec.  1065.750 
through distilled H2O in a sealed vessel or use a device that 
introduces distilled H2O as vapor into a controlled gas flow. 
If the sample does not pass through a dryer during emission testing, 
humidify your test gas to an H2O level at or above the 
maximum expected during emission testing. If the sample passes through a 
dryer during emission testing, you must humidify your test gas to an 
H2O at or above the level determined in Sec.  1065.145(e)(2) 
for that dryer. Use a CO2 span gas concentration at least as 
high as the maximum expected during testing.
    (3) Introduce the humidified CO2 test gas into the sample 
system. You may introduce it downstream of any sample dryer, if one is 
used during testing.
    (4) If the sample is not passed through a dryer during this 
verification test, measure the H2O mole fraction, 
xH2O, of the humidified CO2 test gas as close as 
possible to the inlet of the analyzer. For example, measure dewpoint, 
Tdew, and absolute pressure, ptotal, to calculate 
xH2O. Verify that the H2O content meets 
the requirement in paragraph (d)(2) of this section. If the sample is 
passed through a dryer during this verification test, you must verify 
that the H2O content of the humidified test gas downstream of 
the vessel meets the requirement in paragraph (d)(2) of this section 
based on either direct measurement of the H2O content (e.g., 
dewpoint and pressure) or an estimate based on the vessel pressure and 
temperature. Use good engineering judgment to estimate the 
H2O content. For example, you may use previous direct 
measurements of H2O content to verify the vessel's level of 
saturation.
    (5) If a sample dryer is not used in this verification test, use 
good engineering judgment to prevent condensation in the transfer lines, 
fittings, or valves from the point where xH2O is measured to 
the analyzer. We recommend that you design your system so that the wall 
temperatures in the transfer lines, fittings, and valves from the point 
where xH2O is measured to the analyzer are at least 5 [deg]C 
above the local sample gas dewpoint.
    (6) Allow time for the analyzer response to stabilize. Stabilization 
time may include time to purge the transfer line and to account for 
analyzer response.
    (7) While the analyzer measures the sample's concentration, record 
its output for 30 seconds. Calculate the arithmetic mean of this data.
    (8) The analyzer meets the interference verification if the result 
of paragraph (d)(7) of this section meets the tolerance in paragraph (c) 
of this section.
    (9) You may also run interference procedures for CO2 and 
H2O separately. If the CO2 and H2O 
levels used are higher than the maximum levels expected during testing, 
you may scale down each observed interference value by multiplying the 
observed interference by the ratio of the maximum expected concentration 
value to the actual value used during this procedure. You may run 
separate interference concentrations of H2O (down to 0.025 
mol/mol H2O content) that are lower than the maximum levels 
expected during testing, but you must scale up the observed 
H2O interference by multiplying the observed interference by 
the ratio of the maximum expected H2O concentration value to 
the actual value used during this procedure. The sum of the two scaled 
interference values must meet the tolerance in paragraph (c) of this 
section.
    (e) Exceptions. The following exceptions apply:
    (1) You may omit this verification if you can show by engineering 
analysis that for your CO sampling system and your emission-calculation 
procedures, the combined CO2 and H2O interference 
for your CO NDIR analyzer always affects your brake-specific CO emission 
results within 0.5% of the applicable CO standard.
    (2) You may use a CO NDIR analyzer that you determine does not meet 
this verification, as long as you try to correct the problem and the 
measurement deficiency does not adversely affect

[[Page 130]]

your ability to show that engines comply with all applicable emission 
standards.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37308, June 30, 2008; 
73 FR 59328, Oct. 8, 2008; 75 FR 23041, Apr. 30, 2010; 79 FR 23769, Apr. 
28, 2014; 86 FR 34543, June 29, 2021]

                        Hydrocarbon Measurements



Sec.  1065.360  FID optimization and verification.

    (a) Scope and frequency. For all FID analyzers, calibrate the FID 
upon initial installation. Repeat the calibration as needed using good 
engineering judgment. For a FID that measures THC, perform the following 
steps:
    (1) Optimize the response to various hydrocarbons after initial 
analyzer installation and after major maintenance as described in 
paragraph (c) of this section.
    (2) Determine the methane (CH4) response factor after 
initial analyzer installation and after major maintenance as described 
in paragraph (d) of this section.
    (3) If you determine NMNEHC by subtracting from measured THC, 
determine the ethane (C2H6) response factor after 
initial analyzer installation and after major maintenance as described 
in paragraph (f) of this section. Verify the C2H6 
response within 185 days before testing as described in paragraph (f) of 
this section.
    (4) For any gaseous-fueled engine, including dual-fuel and flexible-
fuel engines, you may determine the methane (CH4) and ethane 
(C2H6) response factors as a function of the molar 
water concentration in the raw or diluted exhaust. If you choose the 
option in this paragraph (a)(4), generate and verify the humidity level 
(or fraction) as described in Sec.  1065.365(d)(11).
    (b) Calibration. Use good engineering judgment to develop a 
calibration procedure, such as one based on the FID-analyzer 
manufacturer's instructions and recommended frequency for calibrating 
the FID. Alternately, you may remove system components for off-site 
calibration. For a FID that measures THC, calibrate using 
C3H8 calibration gases that meet the 
specifications of Sec.  1065.750. For a FID that measures 
CH4, calibrate using CH4 calibration gases that 
meet the specifications of Sec.  1065.750. We recommend FID analyzer 
zero and span gases that contain approximately the flow-weighted mean 
concentration of O2 expected during testing. If you use a FID 
to measure CH4 downstream of a nonmethane cutter, you may 
calibrate that FID using CH4 calibration gases with the 
cutter. Regardless of the calibration gas composition, calibrate on a 
carbon number basis of one (C1). For example, if you use a 
C3H8 span gas of concentration 200 [micro]mol/mol, 
span the FID to respond with a value of 600 [micro]mol/mol. As another 
example, if you use a CH4 span gas with a concentration of 
200 [micro]mol/mol, span the FID to respond with a value of 200 
[micro]mol/mol.
    (c) THC FID response optimization. This procedure is only for FID 
analyzers that measure THC. Use good engineering judgment for initial 
instrument start-up and basic operating adjustment using FID fuel and 
zero air. Heated FIDs must be within their required operating 
temperature ranges. Optimize FID response at the most common analyzer 
range expected during emission testing. Optimization involves adjusting 
flows and pressures of FID fuel, burner air, and sample to minimize 
response variations to various hydrocarbon species in the exhaust. Use 
good engineering judgment to trade off peak FID response to propane 
calibration gases to achieve minimal response variations to different 
hydrocarbon species. For an example of trading off response to propane 
for relative responses to other hydrocarbon species, see SAE 770141 
(incorporated by reference in Sec.  1065.1010). Determine the optimum 
flow rates and/or pressures for FID fuel, burner air, and sample and 
record them for future reference.
    (d) THC FID CH4 response factor determination. This procedure is 
only for FID analyzers that measure THC. Since FID analyzers generally 
have a different response to CH4 versus 
C3H8, determine the THC-FID analyzer's 
CH4 response factor, RFCH4[THC-FID], after FID 
optimization. Use the most recent RFCH4[THC-FID] measured 
according to this section in the calculations for HC determination 
described in Sec.  1065.660 to

[[Page 131]]

compensate for CH4 response. Determine 
RFCH4[THC-FID] as follows, noting that you do not determine 
RFCH4[THC-FID] for FIDs that are calibrated and spanned using 
CH4 with a nonmethane cutter:
    (1) Select a C3 H8 span gas concentration that 
you use to span your analyzers before emission testing. Use only span 
gases that meet the specifications of Sec.  1065.750. Record the 
C3H8 concentration of the gas.
    (2) Select a CH4 span gas concentration that you use to 
span your analyzers before emission testing. Use only span gases that 
meet the specifications of Sec.  1065.750. Record the CH4 
concentration of the gas.
    (3) Start and operate the FID analyzer according to the 
manufacturer's instructions.
    (4) Confirm that the FID analyzer has been calibrated using 
C3H8. Calibrate on a carbon number basis of one 
(C1). For example, if you use a C3 H8 
span gas of concentration 200 [micro]mol/mol, span the FID to respond 
with a value of 600 [micro]mol/mol.
    (5) Zero the FID with a zero gas that you use for emission testing.
    (6) Span the FID with the C3H8 span gas that 
you selected under paragraph (d)(1) of this section.
    (7) Introduce the CH4 span gas that you selected under 
paragraph (d)(2) of this section into the FID analyzer.
    (8) Allow time for the analyzer response to stabilize. Stabilization 
time may include time to purge the analyzer and to account for its 
response.
    (9) While the analyzer measures the CH4 concentration, 
record 30 seconds of sampled data. Calculate the arithmetic mean of 
these values.
    (10) For analyzers with multiple ranges, you need to perform the 
procedure in this paragraph (d) only on a single range.
    (11) Divide the mean measured concentration by the recorded span 
concentration of the CH4 calibration gas. The result is the 
FID analyzer's response factor for CH4, RF 
CH4[THC-FID].
    (12) Determine the response factor as a function of molar water 
concentration and use this response factor to account for the 
CH4 response for NMHC determination described in Sec.  
1065.660(b)(2)(iii). Humidify the CH4 span gas as described 
in Sec.  1065.365(d)(11) and repeat the steps in paragraphs (d)(7) 
through (9) of this section until measurements are complete for each 
setpoint in the selected range. Divide each mean measured CH4 
concentration by the recorded span concentration of the CH4 calibration 
gas, adjusted for water content, to determine the FID analyzer's 
CH4 response factor, RFCH4[THC	FID]. Use the CH4 
response factors at the different setpoints to create a functional 
relationship between response factor and molar water concentration, 
downstream of the last sample dryer if any sample dryers are present. 
Use this functional relationship to determine the response factor during 
an emission test.
    (e) THC FID CH4 response verification. This procedure is 
only for FID analyzers that measure THC. Verify 
RFCH4[THC-FID] as follows:
    (1) Perform a CH4 response factor determination as 
described in paragraph (d) of this section. If the resulting value of 
RFCH4[THC-FID] is within 5% of its most 
recent previously determined value, the THC FID passes the 
CH4 response verification. For example, if the most recent 
previous value for RF CH4[THC-FID] was 1.05 and it increased 
by 0.05 to become 1.10 or it decreased by 0.05 to become 1.00, either 
case would be acceptable because 4.8% is less than 
5%.
    (2) If RF CH4[THC-FID] is not within the tolerance 
specified in paragraph (e)(1) of this section, use good engineering 
judgment to verify that the flow rates and/or pressures of FID fuel, 
burner air, and sample are at their most recent previously recorded 
values, as determined in paragraph (c) of this section. You may adjust 
these flow rates as necessary. Then determine the RF 
CH4[THC-FID] as described in paragraph (d) of this section 
and verify that it is within the tolerance specified in this paragraph 
(e).
    (3) If RF CH4[THC-FID] is not within the tolerance 
specified in this paragraph (e), re-optimize the FID response as 
described in paragraph (c) of this section.
    (4) Determine a new RFCH4[THC-FID] as described in 
paragraph (d) of this section. Use this new value of RF 
CH4[THC-FID] in the calculations for HC

[[Page 132]]

determination, as described in Sec.  1065.660.
    (5) For analyzers with multiple ranges, you need to perform the 
procedure in this paragraph (e) only on a single range.
    (f) THC FID C2H6 response factor 
determination. This procedure is only for FID analyzers that measure 
THC. Since FID analyzers generally have a different response to 
C2H6 than C3H8, determine 
the THC-FID analyzer's C2H6 response factor, 
RFC2H6[THC-FID], after FID optimization using the procedure 
described in paragraph (d) of this section, replacing CH4 
with C2H6. Use the most recent 
RFC2H6[THC-FID] measured according to this section in the 
calculations for HC determination described in Sec.  1065.660 to 
compensate for C2H6 response.

[73 FR 37308, June 30, 2008, as amended at 75 FR 23041, Apr. 30, 2010; 
76 FR 57447, Sept. 15, 2011; 79 FR 23769, Apr. 28, 2014; 81 FR 74168, 
Oct. 25, 2016; 86 FR 34543, June 29, 2021]



Sec.  1065.362  Non-stoichiometric raw exhaust FID O2 interference verification.

    (a) Scope and frequency. If you use FID analyzers for raw exhaust 
measurements from engines that operate in a non-stoichiometric mode of 
combustion (e.g., compression-ignition, lean-burn), verify the amount of 
FID O2 interference upon initial installation and after major 
maintenance.
    (b) Measurement principles. Changes in O2 concentration 
in raw exhaust can affect FID response by changing FID flame 
temperature. Optimize FID fuel, burner air, and sample flow to meet this 
verification. Verify FID performance with the compensation algorithms 
for FID O2 interference that you have active during an 
emission test.
    (c) System requirements. Any FID analyzer used during testing must 
meet the FID O2 interference verification according to the 
procedure in this section.
    (d) Procedure. Determine FID O2 interference as follows, 
noting that you may use one or more gas dividers to create the reference 
gas concentrations that are required to perform this verification:
    (1) Select three span reference gases that contain a 
C3H8 concentration that you use to span your 
analyzers before emission testing. Use only span gases that meet the 
specifications of Sec.  1065.750. You may use CH4 span 
reference gases for FIDs calibrated on CH4 with a nonmethane 
cutter. Select the three balance gas concentrations such that the 
concentrations of O2 and N2 represent the minimum, 
maximum, and average O2 concentrations expected during 
testing. The requirement for using the average O2 
concentration can be removed if you choose to calibrate the FID with 
span gas balanced with the average expected oxygen concentration.
    (2) Confirm that the FID analyzer meets all the specifications of 
Sec.  1065.360.
    (3) Start and operate the FID analyzer as you would before an 
emission test. Regardless of the FID burner's air source during testing, 
use zero air as the FID burner's air source for this verification.
    (4) Zero the FID analyzer using the zero gas used during emission 
testing.
    (5) Span the FID analyzer using a span gas that you use during 
emission testing.
    (6) Check the zero response of the FID analyzer using the zero gas 
used during emission testing. If the mean zero response of 30 seconds of 
sampled data is within 0.5% of the span reference 
value used in paragraph (d)(5) of this section, then proceed to the next 
step; otherwise restart the procedure at paragraph (d)(4) of this 
section.
    (7) Check the analyzer response using the span gas that has the 
minimum concentration of O2 expected during testing. Record 
the mean response of 30 seconds of stabilized sample data as 
xO2minHC.
    (8) Check the zero response of the FID analyzer using the zero gas 
used during emission testing. If the mean zero response of 30 seconds of 
stabilized sample data is within 0.5% of the span 
reference value used in paragraph (d)(5) of this section, then proceed 
to the next step; otherwise restart the procedure at paragraph (d)(4) of 
this section.
    (9) Check the analyzer response using the span gas that has the 
average concentration of O2 expected during testing. Record 
the mean response of 30 seconds of stabilized sample data as 
xO2avgHC.

[[Page 133]]

    (10) Check the zero response of the FID analyzer using the zero gas 
used during emission testing. If the mean zero response of 30 seconds of 
stabilized sample data is within 0.5% of the span 
reference value used in paragraph (d)(5) of this section, proceed to the 
next step; otherwise restart the procedure at paragraph (d)(4) of this 
section.
    (11) Check the analyzer response using the span gas that has the 
maximum concentration of O2 expected during testing. Record 
the mean response of 30 seconds of stabilized sample data as 
xO2maxHC.
    (12) Check the zero response of the FID analyzer using the zero gas 
used during emission testing. If the mean zero response of 30 seconds of 
stabilized sample data is within 0.5% of the span 
reference value used in paragraph (d)(5) of this section, then proceed 
to the next step; otherwise restart the procedure at paragraph (d)(4) of 
this section.
    (13) Calculate the percent difference between xO2maxHC 
and its reference gas concentration. Calculate the percent difference 
between xO2avgHC and its reference gas concentration. 
Calculate the percent difference between xO2minHC and its 
reference gas concentration. Determine the maximum percent difference of 
the three. This is the O2 interference.
    (14) If the O2 interference is within 2%, the FID passes the O2 interference 
verification; otherwise perform one or more of the following to address 
the deficiency:
    (i) Repeat the verification to determine if a mistake was made 
during the procedure.
    (ii) Select zero and span gases for emission testing that contain 
higher or lower O2 concentrations and repeat the 
verification.
    (iii) Adjust FID burner air, fuel, and sample flow rates. Note that 
if you adjust these flow rates on a THC FID to meet the O2 
interference verification, you have reset RFCH4 for the next 
RFCH4 verification according to Sec.  1065.360. Repeat the 
O2 interference verification after adjustment and determine 
RFCH4.
    (iv) Repair or replace the FID and repeat the O2 
interference verification.
    (v) Demonstrate that the deficiency does not adversely affect your 
ability to demonstrate compliance with the applicable emission 
standards.
    (15) For analyzers with multiple ranges, you need to perform the 
procedure in this paragraph (d) only on a single range.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37309, June 30, 2008; 
79 FR 23770, Apr. 28, 2014]



Sec.  1065.365  Nonmethane cutter penetration fractions.

    (a) Scope and frequency. If you use a FID analyzer and a nonmethane 
cutter (NMC) to measure methane (CH4), determine the 
nonmethane cutter's penetration fractions of methane, PFCH4, 
and ethane, PFC2H6. As detailed in this section, these 
penetration fractions may be determined as a combination of NMC 
penetration fractions and FID analyzer response factors, depending on 
your particular NMC and FID analyzer configuration. Perform this 
verification after installing the nonmethane cutter. Repeat this 
verification within 185 days of testing to verify that the catalytic 
activity of the cutter has not deteriorated. Note that because 
nonmethane cutters can deteriorate rapidly and without warning if they 
are operated outside of certain ranges of gas concentrations and outside 
of certain temperature ranges, good engineering judgment may dictate 
that you determine a nonmethane cutter's penetration fractions more 
frequently.
    (b) Measurement principles. A nonmethane cutter is a heated catalyst 
that removes nonmethane hydrocarbons from an exhaust sample stream 
before the FID analyzer measures the remaining hydrocarbon 
concentration. An ideal nonmethane cutter would have a CH4 
penetration fraction, PFCH4, of 1.000, and the penetration 
fraction for all other nonmethane hydrocarbons would be 0.000, as 
represented by PFC2H6. The emission calculations in Sec.  
1065.660 use the measured values from this verification to account for 
less than ideal NMC performance.
    (c) System requirements. We do not limit NMC penetration fractions 
to a certain range. However, we recommend that you optimize a nonmethane 
cutter by adjusting its temperature to achieve

[[Page 134]]

a PFCH4 0.85 and a PFC2H6 <0.02, as 
determined by paragraphs (d), (e), or (f) of this section, as 
applicable. If we use a nonmethane cutter for testing, it will meet this 
recommendation. If adjusting NMC temperature does not result in 
achieving both of these specifications simultaneously, we recommend that 
you replace the catalyst material. Use the most recently determined 
penetration values from this section to calculate HC emissions according 
to Sec.  1065.660 and Sec.  1065.665 as applicable.
    (d) Procedure for a FID calibrated with the NMC. The method 
described in this paragraph (d) is recommended over the procedures 
specified in paragraphs (e) and (f) of this section and required for any 
gaseous-fueled engine, including dual-fuel and flexible-fuel engines. If 
your FID arrangement is such that a FID is always calibrated to measure 
CH4 with the NMC, then span that FID with the NMC using a 
CH4 span gas, set the product of that FID's CH4 
response factor and CH4 penetration fraction, 
RFPFCH4[NMC-FID], equal to 1.0 for all emission calculations, 
and determine its combined C2H6 response factor 
and C2H6 penetration fraction, 
RFPFC2H6[NMC-FID], as follows. For any gaseous-fueled engine, 
including dual-fuel and flexible-fuel engines, you must determine the 
CH4 penetration fraction, PFCH4[NMC-FID], and 
C2H6 response factor and 
C2H6 penetration fraction, 
RFPFC2H6[NMC-FID], as a function of the molar water 
concentration in the raw or diluted exhaust as described in paragraphs 
(d)(10) and (12) of this section. Generate and verify the humidity 
generation as described in paragraph (d)(11) of this section. When using 
the option in this paragraph (d), note that the FID's CH4 
penetration fraction, PFCH4[NMC-FID], is set equal to 1.0 
only for 0% molar water concentration. You are not required to meet the 
recommended lower limit for PFCH4 of greater than 0.85 for 
any of the penetration fractions generated as a function of molar water 
concentration.
    (1) Select CH4 and C2H6 analytical 
gas mixtures and ensure that both mixtures meet the specifications of 
Sec.  1065.750. Select a CH4 concentration that you would use 
for spanning the FID during emission testing and select a 
C2H6 concentration that is typical of the peak 
NMHC concentration expected at the hydrocarbon standard or equal to the 
THC analyzer's span value. For CH4 analyzers with multiple 
ranges, perform this procedure on the highest range used for emission 
testing.
    (2) Start, operate, and optimize the nonmethane cutter according to 
the manufacturer's instructions, including any temperature optimization.
    (3) Confirm that the FID analyzer meets all the specifications of 
Sec.  1065.360.
    (4) Start and operate the FID analyzer according to the 
manufacturer's instructions.
    (5) Zero and span the FID with the nonmethane cutter as you would 
during emission testing. Span the FID through the cutter by using 
CH4 span gas.
    (6) Introduce the C2H6 analytical gas mixture 
upstream of the nonmethane cutter. Use good engineering judgment to 
address the effect of hydrocarbon contamination if your point of 
introduction is vastly different from the point of zero/span gas 
introduction.
    (7) Allow time for the analyzer response to stabilize. Stabilization 
time may include time to purge the nonmethane cutter and to account for 
the analyzer's response.
    (8) While the analyzer measures a stable concentration, record 30 
seconds of sampled data. Calculate the arithmetic mean of these data 
points.
    (9) Divide the mean C2H6 concentration by the 
reference concentration of C2H6, converted to a 
C1 basis. The result is the C2H6 
combined response factor and penetration fraction, 
RFPFC2H6[NMC-FID]. Use this combined 
C2H6 response factor and 
C2H6 penetration fraction and the product of the 
CH4 response factor and CH4 penetration fraction, 
RFPFCH4[NMC-FID], set to 1.0 in emission calculations 
according to Sec.  1065.660(b)(2)(i) or (d)(1)(i) or Sec.  1065.665, as 
applicable.
    (10) Determine the combined C2H6 response 
factor and C2H6 penetration fraction as a function 
of molar water concentration and use it to account for 
C2H6 response factor and 
C2H6 penetration fraction for NMHC determination 
as described in Sec.  1065.660(b)(2)(iii) and for CH4 
determination in Sec.  1065.660(d)(1)(iii). Humidify the 
C2H6 analytical gas mixture as described in

[[Page 135]]

paragraph (d)(11) of this section. Repeat the steps in paragraphs (d)(6) 
through (8) of this section until measurements are complete for each 
setpoint in the selected range. Divide each mean measured 
C2H6 concentration by the reference concentration 
of C2H6, converted to a C1-basis and 
adjusted for water content to determine the FID analyzer's combined 
C2H6 response factor and 
C2H6 penetration fraction, 
RFPFC2H6[NMC-FID]. Use RFPFC2H6[NMC-FID] at the 
different setpoints to create a functional relationship between the 
combined response factor and penetration fraction and molar water 
concentration, downstream of the last sample dryer if any sample dryers 
are present. Use this functional relationship to determine the combined 
response factor and penetration fraction during the emission test.
    (11) Create a humidified test gas by bubbling the analytical gas 
mixture that meets the specifications in Sec.  1065.750 through 
distilled H2O in a sealed vessel or use a device that 
introduces distilled H2O as vapor into a controlled gas flow. 
If the sample does not pass through a dryer during emission testing, 
generate at least five different H2O concentrations that 
cover the range from less than the minimum expected to greater than the 
maximum expected water concentration during testing. Use good 
engineering judgment to determine the target concentrations. For 
analyzers where the sample passes through a dryer during emission 
testing, humidify your test gas to an H2O level at or above 
the level determined in Sec.  1065.145(e)(2) for that dryer and 
determine a single wet analyzer response to the dehumidified sample. 
Heat all transfer lines from the water generation system to a 
temperature at least 5 [deg]C higher than the highest dewpoint 
generated. Determine H2O concentration as an average value 
over intervals of at least 30 seconds. Monitor the humidified sample 
stream with a dewpoint analyzer, relative humidity sensor, FTIR, NDIR, 
or other water analyzer during each test or, if the humidity generator 
achieves humidity levels with controlled flow rates, validate the 
instrument within 370 days before testing and after major maintenance 
using one of the following methods:
    (i) Determine the linearity of each flow metering device. Use one or 
more reference flow meters to measure the humidity generator's flow 
rates and verify the H2O level value based on the humidity 
generator manufacturer's recommendations and good engineering judgment. 
We recommend that you utilize at least 10 flow rates for each flow-
metering device.
    (ii) Perform validation testing based on monitoring the humidified 
stream with a dewpoint analyzer, relative humidity sensor, FTIR, NDIR, 
or other water analyzer as described in this paragraph (d)(11). Compare 
the measured humidity to the humidity generator's value. Verify overall 
linearity performance for the generated humidity as described in Sec.  
1065.307 using the criteria for other dewpoint measurements or confirm 
all measured values are within 2% of the target 
mole fraction. In the case of dry gas, the measured value may not exceed 
0.002 mole fraction.
    (iii) Follow the performance requirements in Sec.  1065.307(b) if 
the humidity generator does not meet validation criteria.
    (12) Determine the CH4 penetration fraction as a function 
of molar water concentration and use this penetration fraction for NMHC 
determination in Sec.  1065.660(b)(2)(iii) and for CH4 
determination in Sec.  1065.660(d)(1)(iii). Repeat the steps in 
paragraphs (d)(6) through (11) of this section, but with the 
CH4 analytical gas mixture instead of 
C2H6. Use this functional relationship to 
determine the penetration fraction during the emission test.
    (e) Procedure for a FID calibrated with propane, bypassing the NMC. 
If you use a single FID for THC and CH4 determination with an 
NMC that is calibrated with propane, C3H8, by 
bypassing the NMC, determine its penetration fractions, 
PFC2H6[NMC-FID] and PFCH4[NMC-FID], as follows:
    (1) Select CH4 and C2H6 analytical 
gas mixtures and ensure that both mixtures meet the specifications of 
Sec.  1065.750. Select a CH4 concentration that you would use 
for spanning the FID during emission testing and select a 
C2H6 concentration that is typical of

[[Page 136]]

the peak NMHC concentration expected at the hydrocarbon standard and the 
C2H6 concentration typical of the peak total 
hydrocarbon (THC) concentration expected at the hydrocarbon standard or 
equal to the THC analyzer's span value. For CH4 analyzers 
with multiple ranges, perform this procedure on the highest range used 
for emission testing.
    (2) Start and operate the nonmethane cutter according to the 
manufacturer's instructions, including any temperature optimization.
    (3) Confirm that the FID analyzer meets all the specifications of 
Sec.  1065.360.
    (4) Start and operate the FID analyzer according to the 
manufacturer's instructions.
    (5) Zero and span the FID as you would during emission testing. Span 
the FID by bypassing the cutter and by using C3H8 
span gas.
    (6) Introduce the C2H6 analytical gas mixture 
upstream of the nonmethane cutter. Use good engineering judgment to 
address the effect of hydrocarbon contamination if your point of 
introduction is vastly different from the point of zero/span gas 
introduction.
    (7) Allow time for the analyzer response to stabilize. Stabilization 
time may include time to purge the nonmethane cutter and to account for 
the analyzer's response.
    (8) While the analyzer measures a stable concentration, record 30 
seconds of sampled data. Calculate the arithmetic mean of these data 
points.
    (9) Reroute the flow path to bypass the nonmethane cutter, introduce 
the C2H6 analytical gas mixture, and repeat the 
steps in paragraph (e)(7) through (e)(8) of this section.
    (10) Divide the mean C2H6 concentration 
measured through the nonmethane cutter by the mean 
C2H6 concentration measured after bypassing the 
nonmethane cutter. The result is the C2H6 
penetration fraction, PFC2H6[NMC-FID]. Use this penetration 
fraction according to Sec.  1065.660(b)(2)(ii), Sec.  
1065.660(d)(1)(ii), or Sec.  1065.665, as applicable.
    (11) Repeat the steps in paragraphs (e)(6) through (e)(10) of this 
section, but with the CH4 analytical gas mixture instead of 
C2H6. The result will be the CH4 
penetration fraction, PFCH4[NMC-FID]. Use this penetration 
fraction according to Sec.  1065.660(b)(2)(ii), Sec.  
1065.660(c)(1)(ii), or Sec.  1065.665, as applicable.
    (f) Procedure for a FID calibrated with CH4, bypassing 
the NMC. If you use a FID with an NMC that is calibrated with 
CH4, by bypassing the NMC, determine its combined ethane 
(C2H6) response factor and penetration fraction, 
RFPFC2H6[NMC-FID], as well as its CH4 penetration 
fraction, PFCH4[NMC-FID], as follows:
    (1) Select CH4 and C2H6 analytical 
gas mixtures and ensure that both mixtures meet the specifications of 
Sec.  1065.750. Select a CH4 concentration that you would use 
for spanning the FID during emission testing and select a 
C2H6 concentration that is typical of the peak 
NMHC concentration expected at the hydrocarbon standard or equal to the 
THC analyzer's span value. For CH4 analyzers with multiple 
ranges, perform this procedure on the highest range used for emission 
testing.
    (2) Start and operate the nonmethane cutter according to the 
manufacturer's instructions, including any temperature optimization.
    (3) Confirm that the FID analyzer meets all the specifications of 
Sec.  1065.360.
    (4) Start and operate the FID analyzer according to the 
manufacturer's instructions.
    (5) Zero and span the FID as you would during emission testing. Span 
the FID by bypassing the cutter and by using CH4 span gas. 
Note that you must span the FID on a C1 basis. For example, 
if your span gas has a methane reference value of 100 [micro]mol/mol, 
the correct FID response to that span gas is 100 [micro]mol/mol because 
there is one carbon atom per CH4 molecule.
    (6) Introduce the C2H6 analytical gas mixture 
upstream of the nonmethane cutter. Use good engineering judgment to 
address the effect of hydrocarbon contamination if your point of 
introduction is vastly different from the point of zero/span gas 
introduction.
    (7) Allow time for the analyzer response to stabilize. Stabilization 
time may include time to purge the nonmethane cutter and to account for 
the analyzer's response.
    (8) While the analyzer measures a stable concentration, record 30 
seconds

[[Page 137]]

of sampled data. Calculate the arithmetic mean of these data points.
    (9) Divide the mean C2H6 concentration by the 
reference concentration of C2H6, converted to a 
C1 basis. The result is the combined 
C2H6 response factor and 
C2H6 penetration fraction, 
RFPFC2H6[NMC-FID]. Use this combined 
C2H6 response factor and 
C2H6 penetration fraction according to Sec.  
1065.660(b)(2)(iii) or (d)(1)(iii) or Sec.  1065.665, as applicable.
    (10) Introduce the CH4 analytical gas mixture upstream of 
the nonmethane cutter. Use good engineering judgment to address the 
effect of hydrocarbon contamination if your point of introduction is 
vastly different from the point of zero/span gas introduction.
    (11) Allow time for the analyzer response to stabilize. 
Stabilization time may include time to purge the nonmethane cutter and 
to account for the analyzer's response.
    (12) While the analyzer measures a stable concentration, record 30 
seconds of sampled data. Calculate the arithmetic mean of these data 
points.
    (13) Reroute the flow path to bypass the nonmethane cutter, 
introduce the CH4 analytical gas mixture, and repeat the 
steps in paragraphs (e)(11) and (12) of this section.
    (14) Divide the mean CH4 concentration measured through 
the nonmethane cutter by the mean CH4 concentration measured 
after bypassing the nonmethane cutter. The result is the CH4 
penetration fraction, PFCH4[NMC-FID]. Use this CH4 
penetration fraction according to Sec.  1065.660(b)(2)(iii) or 
(d)(1)(iii) or Sec.  1065.665, as applicable.

[73 FR 37310, June 30, 2008, as amended at 74 FR 56513, Oct. 30, 2009; 
79 FR 23770, Apr. 28, 2014; 81 FR 74168, Oct. 25, 2016; 86 FR 34543, 
June 29, 2021]



Sec.  1065.366  Interference verification for FTIR analyzers.

    (a) Scope and frequency. If you measure CH4, 
C2H6, NMHC, or NMNEHC using an FTIR analyzer, 
verify the amount of interference after initial analyzer installation 
and after major maintenance.
    (b) Measurement principles. Interference gases can interfere with 
certain analyzers by causing a response similar to the target analyte. 
If the analyzer uses compensation algorithms that utilize measurements 
of other gases to meet this interference verification, simultaneously 
conduct these other measurements to test the compensation algorithms 
during the analyzer interference verification.
    (c) System requirements. An FTIR analyzer must have combined 
interference that is within 2% of the flow-
weighted mean concentration of CH4, NMHC, or NMNEHC expected 
at the standard, though we strongly recommend a lower interference that 
is within 1%.
    (d) Procedure. Perform the interference verification for an FTIR 
analyzer using the same procedure that applies for N2O 
analyzers in Sec.  1065.375(d).

[81 FR 74168, Oct. 25, 2016]



Sec.  1065.369  H2O, CO, and CO2 interference
verification for photoacoustic alcohol analyzers.

    (a) Scope and frequency. If you measure ethanol or methanol using a 
photoacoustic analyzer, verify the amount of H2O, CO, and 
CO2 interference after initial analyzer installation and 
after major maintenance.
    (b) Measurement principles. H2O, CO, and CO2 
can positively interfere with a photoacoustic analyzer by causing a 
response similar to ethanol or methanol. If the photoacoustic analyzer 
uses compensation algorithms that utilize measurements of other gases to 
meet this interference verification, simultaneously conduct these other 
measurements to test the compensation algorithms during the analyzer 
interference verification.
    (c) System requirements. Photoacoustic analyzers must have combined 
interference that is within (0.0 0.5) [micro]mol/
mol. We strongly recommend a lower interference that is within (0.0 
0.25) [micro]mol/mol.
    (d) Procedure. Perform the interference verification by following 
the procedure in Sec.  1065.375(d), comparing the results to paragraph 
(c) of this section.

[79 FR 23770, Apr. 28, 2014]

[[Page 138]]

             NOX and N2O Measurements



Sec.  1065.370  CLD CO2 and H2O quench verification.

    (a) Scope and frequency. If you use a CLD analyzer to measure 
NOX, verify the amount of H2O and CO2 
quench after installing the CLD analyzer and after major maintenance.
    (b) Measurement principles. H2O and CO2 can 
negatively interfere with a CLD's NOX response by collisional 
quenching, which inhibits the chemiluminescent reaction that a CLD 
utilizes to detect NOX. This procedure and the calculations 
in Sec.  1065.675 determine quench and scale the quench results to the 
maximum mole fraction of H2O and the maximum CO2 
concentration expected during emission testing. If the CLD analyzer uses 
quench compensation algorithms that utilize H2O and/or 
CO2 measurement instruments, evaluate quench with these 
instruments active and evaluate quench with the compensation algorithms 
applied.
    (c) System requirements. A CLD analyzer must have a combined 
H2O and CO2 quench of 2% or 
less, though we strongly recommend a quench of 1% 
or less. Combined quench is the sum of the CO2 quench 
determined as described in paragraph (d) of this section, plus the 
H2O quench determined in paragraph (e) of this section.
    (d) CO2 quench verification procedure. Use the following 
method to determine CO2 quench by using a gas divider that 
blends binary span gases with zero gas as the diluent and meets the 
specifications in Sec.  1065.248, or use good engineering judgment to 
develop a different protocol:
    (1) Use PTFE or stainless steel tubing to make necessary 
connections.
    (2) Configure the gas divider such that nearly equal amounts of the 
span and diluent gases are blended with each other.
    (3) If the CLD analyzer has an operating mode in which it detects 
NO-only, as opposed to total NOX, operate the CLD analyzer in 
the NO-only operating mode.
    (4) Use a CO2 span gas that meets the specifications of 
Sec.  1065.750 and a concentration that is approximately twice the 
maximum CO2 concentration expected during emission testing.
    (5) Use an NO span gas that meets the specifications of Sec.  
1065.750 and a concentration that is approximately twice the maximum NO 
concentration expected during emission testing.
    (6) Zero and span the CLD analyzer. Span the CLD analyzer with the 
NO span gas from paragraph (d)(5) of this section through the gas 
divider. Connect the NO span gas to the span port of the gas divider; 
connect a zero gas to the diluent port of the gas divider; use the same 
nominal blend ratio selected in paragraph (d)(2) of this section; and 
use the gas divider's output concentration of NO to span the CLD 
analyzer. Apply gas property corrections as necessary to ensure accurate 
gas division.
    (7) Connect the CO2 span gas to the span port of the gas 
divider.
    (8) Connect the NO span gas to the diluent port of the gas divider.
    (9) While flowing NO and CO2 through the gas divider, 
stabilize the output of the gas divider. Determine the CO2 
concentration from the gas divider output, applying gas property 
correction as necessary to ensure accurate gas division, or measure it 
using an NDIR. Record this concentration, xCO2act, and use it 
in the quench verification calculations in Sec.  1065.675. 
Alternatively, you may use a simple gas blending device and use an NDIR 
to determine this CO2 concentration. If you use an NDIR, it 
must meet the requirements of this part for laboratory testing and you 
must span it with the CO2 span gas from paragraph (d)(4) of 
this section.
    (10) Measure the NO concentration downstream of the gas divider with 
the CLD analyzer. Allow time for the analyzer response to stabilize. 
Stabilization time may include time to purge the transfer line and to 
account for analyzer response. While the analyzer measures the sample's 
concentration, record the analyzer's output for 30 seconds. Calculate 
the arithmetic mean concentration from these data, xNOmeas. 
Record xNOmeas, and use it in the quench verification 
calculations in Sec.  1065.675.
    (11) Calculate the actual NO concentration at the gas divider's 
outlet, xNOact, based on the span gas concentrations and 
xCO2act according to Eq. 1065.675-2. Use the calculated value 
in the quench verification calculations in Eq. 1065.675-1.

[[Page 139]]

    (12) Use the values recorded according to this paragraph (d) and 
paragraph (e) of this section to calculate quench as described in Sec.  
1065.675.
    (e) H2O quench verification procedure. Use the following 
method to determine H2O quench, or use good engineering 
judgment to develop a different protocol:
    (1) Use PTFE or stainless steel tubing to make necessary 
connections.
    (2) If the CLD analyzer has an operating mode in which it detects 
NO-only, as opposed to total NOX, operate the CLD analyzer in 
the NO-only operating mode.
    (3) Use an NO span gas that meets the specifications of Sec.  
1065.750 and a concentration that is near the maximum concentration 
expected during emission testing.
    (4) Zero and span the CLD analyzer. Span the CLD analyzer with the 
NO span gas from paragraph (e)(3) of this section, record the span gas 
concentration as xNOdry, and use it in the quench 
verification calculations in Sec.  1065.675.
    (5) Create a humidified NO span gas by bubbling a NO gas that meets 
the specifications in Sec.  1065.750 through distilled H2O in 
a sealed vessel or use a device that introduces distilled H2O 
as vapor into a controlled gas flow. If the sample does not pass through 
a dryer during emission testing, humidify your test gas to an 
H2O level approximately equal to the maximum mole fraction of 
H2O expected during emission testing. If the humidified NO 
span gas sample does not pass through a sample dryer, the quench 
verification calculations in Sec.  1065.675 scale the measured 
H2O quench to the highest mole fraction of H2O 
expected during emission testing. If the sample passes through a dryer 
during emission testing, you must humidify your test gas to an 
H2O level at or above the level determined in Sec.  
1065.145(e)(2) for that dryer. For this case, the quench verification 
calculations in Sec.  1065.675 do not scale the measured H2O 
quench.
    (6) Introduce the humidified NO test gas into the sample system. You 
may introduce it upstream or downstream of any sample dryer that is used 
during emission testing. Note that the sample dryer must meet the sample 
dryer verification check in Sec.  1065.342.
    (7) Measure the mole fraction of H2O in the humidified NO 
span gas downstream of the sample dryer, xH2Omeas. We 
recommend that you measure xH2Omeas as close as possible to 
the CLD analyzer inlet. You may calculate xH2Omeas from 
measurements of dew point, Tdew, and absolute pressure, 
ptotal.
    (8) Use good engineering judgment to prevent condensation in the 
transfer lines, fittings, or valves from the point where 
xH2Omeas is measured to the analyzer. We recommend that you 
design your system so the wall temperatures in the transfer lines, 
fittings, and valves from the point where xH2Omeas is 
measured to the analyzer are at least 5 [deg]C above the local sample 
gas dew point.
    (9) Measure the humidified NO span gas concentration with the CLD 
analyzer. Allow time for the analyzer response to stabilize. 
Stabilization time may include time to purge the transfer line and to 
account for analyzer response. While the analyzer measures the sample's 
concentration, record the analyzer's output for 30 seconds. Calculate 
the arithmetic mean of these data, xNOwet. Record 
xNOwet and use it in the quench verification calculations in 
Sec.  1065.675.
    (f) Corrective action. If the sum of the H2O quench plus 
the CO2 quench is less than -2% or greater than + 2%, take 
corrective action by repairing or replacing the analyzer. Before running 
emission tests, verify that the corrective action successfully restored 
the analyzer to proper functioning.
    (g) Exceptions. The following exceptions apply:
    (1) You may omit this verification if you can show by engineering 
analysis that for your NOX sampling system and your emission 
calculation procedures, the combined CO2 and H2O 
interference for your NOX CLD analyzer always affects your 
brake-specific NOX emission results within no more than 
1% of the applicable NOX standard. If 
you certify to a combined emission standard (such as a NOX + 
NMHC standard), scale your NOX results to the combined 
standard based on the measured results (after incorporating 
deterioration factors, if applicable). For example, if your final 
NOX + NMHC value is half of the emission standard, double the 
NOX result to

[[Page 140]]

estimate the level of NOX emissions corresponding to the 
applicable standard.
    (2) You may use a NOX CLD analyzer that you determine 
does not meet this verification, as long as you try to correct the 
problem and the measurement deficiency does not adversely affect your 
ability to show that engines comply with all applicable emission 
standards.

[73 FR 59328, Oct. 8, 2008, as amended at 73 FR 73789, Dec. 4, 2008; 75 
FR 23041, Apr. 30, 2010; 76 FR 57447, Sept. 15, 2011; 79 FR 23771, Apr. 
28, 2014; 81 FR 74168, Oct. 25, 2016; 86 FR 34545, June 29, 2021]



Sec.  1065.372  NDUV analyzer HC and H2O interference verification.

    (a) Scope and frequency. If you measure NOX using an NDUV 
analyzer, verify the amount of H2O and hydrocarbon 
interference after initial analyzer installation and after major 
maintenance.
    (b) Measurement principles. Hydrocarbons and H2O can 
positively interfere with an NDUV analyzer by causing a response similar 
to NOX. If the NDUV analyzer uses compensation algorithms 
that utilize measurements of other gases to meet this interference 
verification, simultaneously conduct such measurements to test the 
algorithms during the analyzer interference verification.
    (c) System requirements. A NOX NDUV analyzer must have 
combined H2O and HC interference within 2% of the flow-weighted mean concentration of 
NOX expected at the standard, though we strongly recommend 
keeping interference within 1%.
    (d) Procedure. Perform the interference verification as follows:
    (1) Start, operate, zero, and span the NOX NDUV analyzer 
according to the instrument manufacturer's instructions.
    (2) We recommend that you extract engine exhaust to perform this 
verification. Use a CLD that meets the specifications of subpart C of 
this part to quantify NOX in the exhaust. Use the CLD 
response as the reference value. Also measure HC in the exhaust with a 
FID analyzer that meets the specifications of subpart C of this part. 
Use the FID response as the reference hydrocarbon value.
    (3) Upstream of any sample dryer, if one is used during testing, 
introduce the engine exhaust to the NDUV analyzer.
    (4) Allow time for the analyzer response to stabilize. Stabilization 
time may include time to purge the transfer line and to account for 
analyzer response.
    (5) While all analyzers measure the sample's concentration, record 
30 seconds of sampled data, and calculate the arithmetic means for the 
three analyzers.
    (6) Subtract the CLD mean from the NDUV mean.
    (7) Multiply this difference by the ratio of the flow-weighted mean 
HC concentration expected at the standard to the HC concentration 
measured during the verification. The analyzer meets the interference 
verification of this section if this result is within 2% of the NOX concentration expected at the 
standard.
    (e) Exceptions. The following exceptions apply:
    (1) You may omit this verification if you can show by engineering 
analysis that for your NOX sampling system and your emission 
calculation procedures, the combined HC and H2O interference 
for your NOX NDUV analyzer always affects your brake-specific 
NOX emission results by less than 0.5% of the applicable 
NOX standard.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37312, June 30, 2008; 
76 FR 57447, Sept. 15, 2011]



Sec.  1065.375  Interference verification for N2O analyzers.

    (a) Scope and frequency. See Sec.  1065.275 to determine whether you 
need to verify the amount of interference after initial analyzer 
installation and after major maintenance.
    (b) Measurement principles. Interference gases can positively 
interfere with certain analyzers by causing a response similar to 
N2O. If the analyzer uses compensation algorithms that 
utilize measurements of other gases to meet this interference 
verification, simultaneously conduct these other

[[Page 141]]

measurements to test the compensation algorithms during the analyzer 
interference verification.
    (c) System requirements. Analyzers must have combined interference 
that is within (0.0 1.0) [micro]mol/mol. We 
strongly recommend a lower interference that is within (0.0 0.5) [micro]mol/mol.
    (d) Procedure. Perform the interference verification as follows:
    (1) Start, operate, zero, and span the N2O analyzer as 
you would before an emission test. If the sample is passed through a 
dryer during emission testing, you may run this verification test with 
the dryer if it meets the requirements of Sec.  1065.342. Operate the 
dryer at the same conditions as you will for an emission test. You may 
also run this verification test without the sample dryer.
    (2) Create a humidified test gas by bubbling a multi component span 
gas that incorporates the target interference species and meets the 
specifications in Sec.  1065.750 through distilled H2O in a 
sealed vessel or use a device that introduces distilled H2O 
as vapor into a controlled gas flow. If the sample does not pass through 
a dryer during emission testing, humidify your test gas to an 
H2O level at or above the maximum expected during emission 
testing. If the sample passes through a dryer during emission testing, 
you must humidify your test gas to an H2O level at or above 
the level determined in Sec.  1065.145(e)(2) for that dryer. Use 
interference span gas concentrations that are at least as high as the 
maximum expected during testing.
    (3) Introduce the humidified interference test gas into the sample 
system. You may introduce it downstream of any sample dryer, if one is 
used during testing.
    (4) If the sample is not passed through a dryer during this 
verification test, measure the H2O mole fraction, 
xH2O, of the humidified interference test gas as 
close as possible to the inlet of the analyzer. For example, measure 
dewpoint, Tdew, and absolute pressure, ptotal, to 
calculate xH2O. Verify that the H2O 
content meets the requirement in paragraph (d)(2) of this section. If 
the sample is passed through a dryer during this verification test, you 
must verify that the H2O content of the humidified test gas 
downstream of the vessel meets the requirement in paragraph (d)(2) of 
this section based on either direct measurement of the H2O 
content (e.g., dewpoint and pressure) or an estimate based on the vessel 
pressure and temperature. Use good engineering judgment to estimate the 
H2O content. For example, you may use previous direct 
measurements of H2O content to verify the vessel's level of 
saturation.
    (5) If a sample dryer is not used in this verification test, use 
good engineering judgment to prevent condensation in the transfer lines, 
fittings, or valves from the point where xH2O is 
measured to the analyzer. We recommend that you design your system so 
that the wall temperatures in the transfer lines, fittings, and valves 
from the point where xH2O is measured to the 
analyzer are at least 5 [ordm]C above the local sample gas dewpoint.
    (6) Allow time for the analyzer response to stabilize. Stabilization 
time may include time to purge the transfer line and to account for 
analyzer response.
    (7) While the analyzer measures the sample's concentration, record 
its output for 30 seconds. Calculate the arithmetic mean of this data. 
When performed with all the gases simultaneously, this is the combined 
interference.
    (8) The analyzer meets the interference verification if the result 
of paragraph (d)(7) of this section meets the tolerance in paragraph (c) 
of this section.
    (9) You may also run interference procedures separately for 
individual interference gases. If the interference gas levels used are 
higher than the maximum levels expected during testing, you may scale 
down each observed interference value (the arithmetic mean of 30 second 
data described in paragraph (d)(7) of this section) by multiplying the 
observed interference by the ratio of the maximum expected concentration 
value to the actual value used during this procedure. You may run 
separate interference concentrations of H2O (down to 0.025 
mol/mol H2O content) that are lower than the maximum levels 
expected during testing, but you must scale up the observed 
H2O

[[Page 142]]

interference by multiplying the observed interference by the ratio of 
the maximum expected H2O concentration value to the actual 
value used during this procedure. The sum of the scaled interference 
values must meet the tolerance for combined interference as specified in 
paragraph (c) of this section.

[74 FR 56515, Oct. 30, 2009, as amended at 23771, Apr. 28, 2014; 81 FR 
74168, Oct. 25, 2016; 86 FR 34545, June 29, 2021]



Sec.  1065.376  Chiller NO2 penetration.

    (a) Scope and frequency. If you use a chiller to dry a sample 
upstream of a NOX measurement instrument, but you don't use 
an NO2-to-NO converter upstream of the chiller, you must 
perform this verification for chiller NO2 penetration. 
Perform this verification after initial installation and after major 
maintenance.
    (b) Measurement principles. A chiller removes H2O, which 
can otherwise interfere with a NOX measurement. However, 
liquid H2O remaining in an improperly designed chiller can 
remove NO2 from the sample. If a chiller is used without an 
NO2-to-NO converter upstream, it could remove NO2 
from the sample prior NOX measurement.
    (c) System requirements. A chiller must allow for measuring at least 
95% of the total NO2 at the maximum expected concentration of 
NO2.
    (d) Procedure. Use the following procedure to verify chiller 
performance:
    (1) Instrument setup. Follow the analyzer and chiller manufacturers' 
start-up and operating instructions. Adjust the analyzer and chiller as 
needed to optimize performance.
    (2) Equipment setup and data collection. (i) Zero and span the total 
NOX gas analyzer(s) as you would before emission testing.
    (ii) Select an NO2 calibration gas, balance gas of dry 
air, that has an NO2 concentration within 5% of the maximum NO2 concentration expected 
during testing.
    (iii) Overflow this calibration gas at the gas sampling system's 
probe or overflow fitting. Allow for stabilization of the total 
NOX response, accounting only for transport delays and 
instrument response.
    (iv) Calculate the mean of 30 seconds of recorded total 
NOX data and record this value as xNOXref.
    (v) Stop flowing the NO2 calibration gas.
    (vi) Next saturate the sampling system by overflowing a dewpoint 
generator's output, set at a dewpoint of 50 [deg]C, to the gas sampling 
system's probe or overflow fitting. Sample the dewpoint generator's 
output through the sampling system and chiller for at least 10 minutes 
until the chiller is expected to be removing a constant rate of 
H2O.
    (vii) Immediately switch back to overflowing the NO2 
calibration gas used to establish xNOxref. Allow for 
stabilization of the total NOX response, accounting only for 
transport delays and instrument response. Calculate the mean of 30 
seconds of recorded total NOX data and record this value as 
xNOxmeas.
    (viii) Correct xNOxmeas to xNOxdry based upon 
the residual H2O vapor that passed through the chiller at the 
chiller's outlet temperature and pressure.
    (3) Performance evaluation. If xNOxdry is less than 95% 
of xNOxref, repair or replace the chiller.
    (e) Exceptions. The following exceptions apply:
    (1) You may omit this verification if you can show by engineering 
analysis that for your NOX sampling system and your emission 
calculations procedures, the chiller always affects your brake-specific 
NOX emission results by less than 0.5% of the applicable 
NOX standard.
    (2) You may use a chiller that you determine does not meet this 
verification, as long as you try to correct the problem and the 
measurement deficiency does not adversely affect your ability to show 
that engines comply with all applicable emission standards.

[73 FR 37312, June 30, 2008, as amended at 79 FR 23771, Apr. 28, 2014]



Sec.  1065.378  NO2-to-NO converter conversion verification.

    (a) Scope and frequency. If you use an analyzer that measures only 
NO to determine NOX, you must use an NO2-to-NO 
converter upstream of the analyzer.

[[Page 143]]

Perform this verification after installing the converter, after major 
maintenance and within 35 days before an emission test. This 
verification must be repeated at this frequency to verify that the 
catalytic activity of the NO2-to-NO converter has not 
deteriorated.
    (b) Measurement principles. An NO2-to-NO converter allows 
an analyzer that measures only NO to determine total NOX by 
converting the NO2 in exhaust to NO.
    (c) System requirements. An NO2-to-NO converter must 
allow for measuring at least 95% of the total NO2 at the 
maximum expected concentration of NO2.
    (d) Procedure. Use the following procedure to verify the performance 
of a NO2-to-NO converter:
    (1) Instrument setup. Follow the analyzer and NO2-to-NO 
converter manufacturers' start-up and operating instructions. Adjust the 
analyzer and converter as needed to optimize performance.
    (2) Equipment setup. Connect an ozonator's inlet to a zero-air or 
oxygen source and connect its outlet to one port of a three-way tee 
fitting. Connect an NO span gas to another port, and connect the 
NO2-to-NO converter inlet to the last port.
    (3) Adjustments and data collection. Perform this check as follows:
    (i) Set ozonator air off, turn ozonator power off, and set the 
analyzer to NO mode. Allow for stabilization, accounting only for 
transport delays and instrument response.
    (ii) Use an NO concentration that is representative of the peak 
total NOX concentration expected during testing. The 
NO2 content of the gas mixture shall be less than 5% of the 
NO concentration. Record the concentration of NO by calculating the mean 
of 30 seconds of sampled data from the analyzer and record this value as 
xNOref.
    (iii) Turn on the ozonator O2 supply and adjust the 
O2 flow rate so the NO indicated by the analyzer is about 10 
percent less than xNOref. Record the concentration of NO by 
calculating the mean of 30 seconds of sampled data from the analyzer and 
record this value as xNO + O2mix.
    (iv) Switch the ozonator on and adjust the ozone generation rate so 
the NO measured by the analyzer is 20 percent of xNOref or a 
value which would simulate the maximum concentration of NO2 
expected during testing, while maintaining at least 10 percent unreacted 
NO. This ensures that the ozonator is generating NO2 at the 
maximum concentration expected during testing. Record the concentration 
of NO by calculating the mean of 30 seconds of sampled data from the 
analyzer and record this value as xNOmeas.
    (v) Switch the NOX analyzer to NOX mode and 
measure total NOX. Record the concentration of NOX 
by calculating the mean of 30 seconds of sampled data from the analyzer 
and record this value as xNOxmeas.
    (vi) Switch off the ozonator but maintain gas flow through the 
system. The NOX analyzer will indicate the NOX in 
the NO + O2 mixture. Record the concentration of 
NOX by calculating the mean of 30 seconds of sampled data 
from the analyzer and record this value as xNOx + O2mix.
    (vii) Turn off the ozonator O2 supply. The NOX 
analyzer will indicate the NOX in the original NO-in-
N2 mixture. Record the concentration of NOX by 
calculating the mean of 30 seconds of sampled data from the analyzer and 
record this value as xNOxref. This value should be no more 
than 5 percent above the xNOref value.
    (4) Performance evaluation. Calculate the efficiency of the 
NOX converter by substituting the concentrations obtained 
into the following equation:
[GRAPHIC] [TIFF OMITTED] TR08OC08.097


[[Page 144]]


    (5) If the result is less than 95%, repair or replace the 
NO2-to-NO converter.
    (e) Exceptions. The following exceptions apply:
    (1) You may omit this verification if you can show by engineering 
analysis that for your NOX sampling system and your emission 
calculations procedures, the converter always affects your brake-
specific NOX emission results by less than 0.5% of the 
applicable NOX standard.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37313, June 30, 2008; 
73 FR 59330, Oct. 8, 2008; 76 FR 57447, Sept. 15, 2011]

                             PM Measurements



Sec.  1065.390  PM balance verifications and weighing process verification.

    (a) Scope and frequency. This section describes three verifications.
    (1) Independent verification of PM balance performance within 370 
days before weighing any filter.
    (2) Zero and span the balance within 12 h before weighing any 
filter.
    (3) Verify that the mass determination of reference filters before 
and after a filter weighing session are less than a specified tolerance.
    (b) Independent verification. Have the balance manufacturer (or a 
representative approved by the balance manufacturer) verify the balance 
performance within 370 days of testing. Balances have internal weights 
that compensate for drift due to environmental changes. These internal 
weights must be verified as part of this independent verification with 
external, certified calibration weights that meet the specifications in 
Sec.  1065.790.
    (c) Zeroing and spanning. You must verify balance performance by 
zeroing and spanning it with at least one calibration weight. Also, any 
external weights you use must meet the specifications in Sec.  1065.790. 
Any weights internal to the PM balance used for this verification must 
be verified as described in paragraph (b) of this section.
    (1) Use a manual procedure in which you zero the balance and span 
the balance with at least one calibration weight. If you normally use 
mean values by repeating the weighing process to improve the accuracy 
and precision of PM measurements, use the same process to verify balance 
performance.
    (2) You may use an automated procedure to verify balance 
performance. For example most balances have internal weights for 
automatically verifying balance performance.
    (d) Reference sample weighing. Verify all mass readings during a 
weighing session by weighing reference PM sample media (e.g., filters) 
before and after a weighing session. A weighing session may be as short 
as desired, but no longer than 80 hours, and may include both pre-test 
and post-test mass readings. We recommend that weighing sessions be 
eight hours or less. Successive mass determinations of each reference PM 
sample media (e.g., filter) must return the same value within 10 [micro]g or 10% of the net PM 
mass expected at the standard (if known), whichever is higher. If 
successive reference PM sample media (e.g., filter) weighing events fail 
this criterion, invalidate all individual test media (e.g., filter) mass 
readings occurring between the successive reference media (e.g., filter) 
mass determinations. You may reweigh these media (e.g., filter) in 
another weighing session. If you invalidate a pre-test media (e.g., 
filter) mass determination, that test interval is void. Perform this 
verification as follows:
    (1) Keep at least two samples of unused PM sample media (e.g., 
filters) in the PM-stabilization environment. Use these as references. 
If you collect PM with filters, select unused filters of the same 
material and size for use as references. You may periodically replace 
references, using good engineering judgment.
    (2) Stabilize references in the PM stabilization environment. 
Consider references stabilized if they have been in the PM-stabilization 
environment for a minimum of 30 min, and the PM-stabilization 
environment has been within the specifications of Sec.  1065.190(d) for 
at least the preceding 60 min.
    (3) Exercise the balance several times with a reference sample. We 
recommend weighing ten samples without recording the values.
    (4) Zero and span the balance. Using good engineering judgment, 
place a test mass such as a calibration weight on the balance, then 
remove it. After

[[Page 145]]

spanning, confirm that the balance returns to a zero reading within the 
normal stabilization time.
    (5) Weigh each of the reference media (e.g., filters) and record 
their masses. We recommend using substitution weighing as described in 
Sec.  1065.590(j). If you normally use mean values by repeating the 
weighing process to improve the accuracy and precision of the reference 
media (e.g., filter) mass, you must use mean values of sample media 
(e.g., filter) masses.
    (6) Record the balance environment dewpoint, ambient temperature, 
and atmospheric pressure.
    (7) Use the recorded ambient conditions to correct results for 
buoyancy as described in Sec.  1065.690. Record the buoyancy-corrected 
mass of each of the references.
    (8) Subtract each reference media's (e.g., filter's) buoyancy-
corrected reference mass from its previously measured and recorded 
buoyancy-corrected mass.
    (9) If any of the reference filters' observed mass changes by more 
than that allowed under this paragraph, you must invalidate all PM mass 
determinations made since the last successful reference media (e.g. 
filter) mass validation. You may discard reference PM media (e.g. 
filters) if only one of the filter's mass changes by more than the 
allowable amount and you can positively identify a special cause for 
that filter's mass change that would not have affected other in-process 
filters. Thus, the validation can be considered a success. In this case, 
you do not have to include the contaminated reference media when 
determining compliance with paragraph (d)(10) of this section, but the 
affected reference filter must be immediately discarded and replaced 
prior to the next weighing session.
    (10) If any of the reference masses change by more than that allowed 
under this paragraph (d), invalidate all PM results that were determined 
between the two times that the reference masses were determined. If you 
discarded reference PM sample media according to paragraph (d)(9) of 
this section, you must still have at least one reference mass difference 
that meets the criteria in this paragraph (d). Otherwise, you must 
invalidate all PM results that were determined between the two times 
that the reference media (e.g., filters) masses were determined.

[73 FR 37313, June 30, 2008, as amended at 75 FR 23042, Apr. 30, 2010; 
75 FR 68463, Nov. 8, 2010; 81 FR 74168, Oct. 25, 2016]



Sec.  1065.395  Inertial PM balance verifications.

    This section describes how to verify the performance of an inertial 
PM balance.
    (a) Independent verification. Have the balance manufacturer (or a 
representative approved by the balance manufacturer) verify the inertial 
balance performance within 370 days before testing.
    (b) Other verifications. Perform other verifications using good 
engineering judgment and instrument manufacturer recommendations.



        Subpart E_Engine Selection, Preparation, and Maintenance



Sec.  1065.401  Test engine selection.

    While all engine configurations within a certified engine family 
must comply with the applicable standards in the standard-setting part, 
you need not test each configuration for certification.
    (a) Select an engine configuration within the engine family for 
testing, as follows:
    (1) Test the engine that we specify, whether we issue general 
guidance or give you specific instructions.
    (2) If we do not tell you which engine to test, follow any 
instructions in the standard-setting part.
    (3) If we do not tell you which engine to test and the standard-
setting part does not include specifications for selecting test engines, 
use good engineering judgment to select the engine configuration within 
the engine family that is most likely to exceed an emission standard.
    (b) In the absence of other information, the following 
characteristics are appropriate to consider when selecting the engine to 
test:
    (1) Maximum fueling rates.
    (2) Maximum loads.
    (3) Maximum in-use speeds.
    (4) Highest sales volume.

[[Page 146]]

    (c) For our testing, we may select any engine configuration within 
the engine family.



Sec.  1065.405  Test engine preparation and maintenance.

    This part 1065 describes how to test engines for a variety of 
purposes, including certification testing, production-line testing, and 
in-use testing. Depending on which type of testing is being conducted, 
different preparation and maintenance requirements apply for the test 
engine.
    (a) If you are testing an emission-data engine for certification, 
make sure it is built to represent production engines, consistent with 
paragraph (f) of this section.
    (1) This includes governors that you normally install on production 
engines. Production engines should also be tested with their installed 
governors. If your engine is equipped with multiple user-selectable 
governor types and if the governor does not manipulate the emission 
control system (i.e., the governor only modulates an ``operator demand'' 
signal such as commanded fuel rate, torque, or power), choose the 
governor type that allows the test cell to most accurately follow the 
duty cycle. If the governor manipulates the emission control system, 
treat it as an adjustable parameter. If you do not install governors on 
production engines, simulate a governor that is representative of a 
governor that others will install on your production engines.
    (2) In certain circumstances, you may incorporate test cell 
components to simulate an in-use configuration, consistent with good 
engineering judgment. For example, Sec. Sec.  1065.122 and 1065.125 
allow the use of test cell components to represent engine cooling and 
intake air systems.
    (3) The provisions in Sec.  1065.110(e) also apply to emission-data 
engines for certification.
    (4) For engines using SCR, use any size DEF tank and fuel tank. We 
may require you to give us a production-type DEF tank, including any 
associated sensors, for our testing.
    (b) We may set adjustable parameters to any value in the valid 
range, and you are responsible for controlling emissions over the full 
valid range. For each adjustable parameter, if the standard-setting part 
has no unique requirements and if we have not specified a value, use 
good engineering judgment to select the most common setting. If 
information on the most common setting is not available, select the 
setting representing the engine's original shipped configuration. If 
information on the most common and original settings is not available, 
set the adjustable parameter in the middle of the valid range.
    (c) Testing generally occurs only after the test engine has 
undergone a stabilization step (or in-use operation). If the engine has 
not already been stabilized, run the test engine, with all emission 
control systems operating, long enough to stabilize emission levels. 
Note that you must generally use the same stabilization procedures for 
emission-data engines for which you apply the same deterioration factors 
so low-hour emission-data engines are consistent with the low-hour 
engine used to develop the deterioration factor.
    (1) Unless otherwise specified in the standard-setting part, you may 
consider emission levels stable without measurement after 50 h of 
operation. If the engine needs less operation to stabilize emission 
levels, record your reasons and the methods for doing this, and give us 
these records if we ask for them. If the engine will be tested for 
certification as a low-hour engine, see the standard-setting part for 
limits on testing engines to establish low-hour emission levels.
    (2) You may stabilize emissions from a catalytic exhaust 
aftertreatment device by operating it on a different engine, consistent 
with good engineering judgment. Note that good engineering judgment 
requires that you consider both the purpose of the test and how your 
stabilization method will affect the development and application of 
deterioration factors. For example, this method of stabilization is 
generally not appropriate for production engines. We may also allow you 
to stabilize emissions from a catalytic exhaust aftertreatment device by 
operating it on an engine-exhaust simulator.
    (d) Record any maintenance, modifications, parts changes, diagnostic 
or

[[Page 147]]

emissions testing and document the need for each event. You must provide 
this information if we request it.
    (e) For accumulating operating hours on your test engines, select 
engine operation that represents normal in-use operation for the engine 
family.
    (f) If your engine will be used in a vehicle equipped with a 
canister for storing evaporative hydrocarbons for eventual combustion in 
the engine and the test sequence involves a cold-start or hot-start duty 
cycle, attach a canister to the engine before running an emission test. 
You may omit using an evaporative canister for any hot-stabilized duty 
cycles. You may request to omit using an evaporative canister during 
testing if you can show that it would not affect your ability to show 
compliance with the applicable emission standards. You may operate the 
engine without an installed canister for service accumulation. Prior to 
an emission test, use the following steps to precondition a canister and 
attach it to your engine:
    (1) Use a canister and plumbing arrangement that represents the in-
use configuration of the largest capacity canister in all expected 
applications.
    (2) Precondition the canister as described in 40 CFR 86.132-96(j).
    (3) Connect the canister's purge port to the engine.
    (4) Plug the canister port that is normally connected to the fuel 
tank.
    (g) This paragraph (g) defines the components that are considered to 
be part of the engine for laboratory testing. See Sec.  1065.110 for 
provisions related to system boundaries with respect to work inputs and 
outputs.
    (1) This paragraph (g)(1) describes certain criteria for considering 
a component to be part of the test engine. The criteria are intended to 
apply broadly, such that a component would generally be considered part 
of the engine in cases of uncertainty. Except as specified in paragraph 
(g)(2) of this section, an engine-related component meeting both the 
following criteria is considered to be part of the test engine for 
purposes of testing and for stabilizing emission levels, 
preconditioning, and measuring emission levels:
    (i) The component directly affects the functioning of the engine, is 
related to controlling emissions, or transmits engine power. This would 
include engine cooling systems, engine controls, and transmissions.
    (ii) The component is covered by the applicable certificate of 
conformity. For example, this criterion would typically exclude 
radiators not described in an application for certification.
    (2) This paragraph (g)(2) applies for engine-related components that 
meet the criteria of paragraph (g)(1) of this section, but that are part 
of the laboratory setup or are used for other engines. Such components 
are considered to be part of the test engine for preconditioning, but 
not for engine stabilization. For example, if you test your engines 
using the same laboratory exhaust tubing for all tests, there would be 
no restrictions on the number of test hours that could be accumulated 
with the tubing, but it would need to be preconditioned separately for 
each engine.

[79 FR 23772, Apr. 28, 2014, as amended at 88 FR 4675, Jan. 24, 2023]



Sec.  1065.410  Maintenance limits for stabilized test engines.

    (a) After you stabilize the test engine's emission levels, you may 
do maintenance as allowed by the standard-setting part. However, you may 
not do any maintenance based on emission measurements from the test 
engine (i.e., unscheduled maintenance).
    (b) For any critical emission-related maintenance--other than what 
we specifically allow in the standard-setting part--you must completely 
test an engine for emissions before and after doing any maintenance that 
might affect emissions, unless we waive this requirement.
    (c) If you inspect an engine, keep a record of the inspection and 
update your application for certification to document any changes that 
result. You may use any kind of equipment, instrument, or tool that is 
available at dealerships and other service outlets to identify 
malfunctioning components or perform maintenance. You may inspect using 
electronic tools or internal engine systems to monitor engine 
performance, but only if the information is readable without specialized 
equipment.

[[Page 148]]

    (d) You may repair defective parts from a test engine if they are 
unrelated to emission control. You must ask us to approve repairs that 
might affect the engine's emission controls. If we determine that a part 
failure, system malfunction, or associated repair makes the engine's 
emission controls unrepresentative of production engines, you may not 
use it as an emission-data engine. Also, if your test engine has a major 
mechanical failure that requires you to take it apart, you may no longer 
use it as an emission-data engine.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37314, June 30, 2008; 
79 FR 23773, Apr. 28, 2014; 80 FR 9118, Feb. 19, 2015; 86 FR 34545, June 
29, 2021; 88 FR 4675, Jan. 24, 2023]



Sec.  1065.415  Durability demonstration.

    If the standard-setting part requires durability testing, you must 
accumulate service in a way that represents how you expect the engine to 
operate in use. You may accumulate service hours using an accelerated 
schedule, such as through continuous operation or by using duty cycles 
that are more aggressive than in-use operation, subject to any pre-
approval requirements established in the applicable standard-setting 
part.
    (a) Maintenance. The following limits apply to the maintenance that 
we allow you to do on an emission-data engine:
    (1) You may perform scheduled maintenance that you recommend to 
operators, but only if it is consistent with the standard-setting part's 
restrictions.
    (2) You may perform additional maintenance only as specified in 
Sec.  1065.410 or allowed by the standard-setting part.
    (b) Emission measurements. Perform emission tests following the 
provisions of the standard setting part and this part, as applicable. 
Perform emission tests to determine deterioration factors consistent 
with good engineering judgment. Evenly space any tests between the first 
and last test points throughout the durability period, unless we approve 
otherwise.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37315, June 30, 2008]



    Subpart F_Performing an Emission Test Over Specified Duty Cycles



Sec.  1065.501  Overview.

    (a) Use the procedures detailed in this subpart to measure engine 
emissions over a specified duty cycle. Refer to subpart J of this part 
for field test procedures that describe how to measure emissions during 
in-use engine operation. Refer to subpart L of this part for measurement 
procedures for testing related to standards other than brake-specific 
emission standards. This section describes how to--
    (1) Map your engine, if applicable, by recording specified speed and 
torque data, as measured from the engine's primary output shaft.
    (2) Transform normalized duty cycles into reference duty cycles for 
your engine by using an engine map.
    (3) Prepare your engine, equipment, and measurement instruments for 
an emission test.
    (4) Perform pre-test procedures to verify proper operation of 
certain equipment and analyzers.
    (5) Record pre-test data.
    (6) Start or restart the engine and sampling systems.
    (7) Sample emissions throughout the duty cycle.
    (8) Record post-test data.
    (9) Perform post-test procedures to verify proper operation of 
certain equipment and analyzers.
    (10) Weigh PM samples.
    (b) Unless we specify otherwise, you may control the regeneration 
timing of infrequently regenerated aftertreatment devices such as diesel 
particulate filters using good engineering judgment. You may control the 
regeneration timing using a sequence of engine operating conditions or 
you may initiate regeneration with an external regeneration switch or 
other command. This provision also allows you to ensure that a 
regeneration event does not occur during an emission test.
    (c) An emission test generally consists of measuring emissions and 
other parameters while an engine follows one or more duty cycles that 
are specified in the standard-setting part. There are two general types 
of duty cycles:

[[Page 149]]

    (1) Transient cycles. Transient duty cycles are typically specified 
in the standard-setting part as a second-by-second sequence of speed 
commands and normalized torque (or power) commands. Operate an engine 
over a transient cycle such that the speed and torque of the engine's 
primary output shaft follows the target values. Proportionally sample 
emissions and other parameters and use the calculations in subpart G of 
this part to calculate emissions. Start a transient test according to 
the standard-setting part, as follows:
    (i) A cold-start transient cycle where you start to measure 
emissions just before starting an engine that has not been warmed up.
    (ii) A hot-start transient cycle where you start to measure 
emissions just before starting a warmed-up engine.
    (iii) A hot running transient cycle where you start to measure 
emissions after an engine is started, warmed up, and running.
    (2) Steady-state cycles. Steady-state duty cycles are typically 
specified in the standard-setting part as a list of discrete operating 
points (modes or notches), where each operating point has one value of a 
normalized speed command and one value of a normalized torque (or power) 
command. Ramped-modal cycles for steady-state testing also list test 
times for each mode and transition times between modes where speed and 
torque are linearly ramped between modes, even for cycles with % power. 
Start a steady-state cycle as a hot running test, where you start to 
measure emissions after an engine is started, warmed up and running. Run 
a steady-state duty cycle as a discrete-mode cycle or a ramped-modal 
cycle, as follows:
    (i) Discrete-mode cycles. Before emission sampling, stabilize an 
engine at the first discrete mode of the duty cycle specified in the 
standard-setting part. Sample emissions and other parameters for that 
mode in the same manner as a transient cycle, with the exception that 
reference speed and torque values are constant. Record data for that 
mode, transition to the next mode, and then stabilize the engine at the 
next mode. Continue to sample each mode discretely as a separate test 
interval and calculate composite brake-specific emission results 
according to Sec.  1065.650(g)(2).
    (A) Use good engineering judgment to determine the time required to 
stabilize the engine. You may make this determination before starting 
the test based on prior experience, or you may make this determination 
in real time based an automated stability criteria. If needed, you may 
continue to operate the engine after reaching stability to get 
laboratory equipment ready for sampling.
    (B) Collect PM on separate PM sample media for each mode.
    (C) The minimum sample time is 60 seconds. We recommend that you 
sample both gaseous and PM emissions over the same test interval. If you 
sample gaseous and PM emissions over different test intervals, there 
must be no change in engine operation between the two test intervals. 
These two test intervals may completely or partially overlap, they may 
run consecutively, or they may be separated in time.
    (ii) Ramped-modal cycles. Perform ramped-modal cycles similar to the 
way you would perform transient cycles, except that ramped-modal cycles 
involve mostly steady-state engine operation. Generate a ramped-modal 
duty cycle as a sequence of second-by-second (1 Hz) reference speed and 
torque points. Run the ramped-modal duty cycle in the same manner as a 
transient cycle and use the 1 Hz reference speed and torque values to 
validate the cycle, even for cycles with % power. Proportionally sample 
emissions and other parameters during the cycle and use the calculations 
in subpart G of this part to calculate emissions.
    (d) Other subparts in this part identify how to select and prepare 
an engine for testing (subpart E), how to perform the required engine 
service accumulation (subpart E), and how to calculate emission results 
(subpart G).
    (e) Subpart J of this part describes how to perform field testing.

[79 FR 23773, Apr. 28, 2014, as amended at 88 FR 4676, Jan. 24, 2023]



Sec.  1065.510  Engine mapping.

    (a) Applicability, scope, and frequency. An engine map is a data set 
that consists of a series of paired data points

[[Page 150]]

that represent the maximum brake torque versus engine speed, measured at 
the engine's primary output shaft. Map your engine if the standard-
setting part requires engine mapping to generate a duty cycle for your 
engine configuration. Map your engine while it is connected to a 
dynamometer or other device that can absorb work output from the 
engine's primary output shaft according to Sec.  1065.110. Configure any 
auxiliary work inputs and outputs such as hybrid, turbo-compounding, or 
thermoelectric systems to represent their in-use configurations, and use 
the same configuration for emission testing. See Figure 1 of Sec.  
1065.210. This may involve configuring initial states of charge and 
rates and times of auxiliary-work inputs and outputs. We recommend that 
you contact the EPA Program Officer before testing to determine how you 
should configure any auxiliary-work inputs and outputs. If your engine 
has an auxiliary emission control device to reduce torque output that 
may activate during engine mapping, turn it off before mapping. Use the 
most recent engine map to transform a normalized duty cycle from the 
standard-setting part to a reference duty cycle specific to your engine. 
Normalized duty cycles are specified in the standard-setting part. You 
may update an engine map at any time by repeating the engine-mapping 
procedure. You must map or re-map an engine before a test if any of the 
following apply:
    (1) If you have not performed an initial engine map.
    (2) If the atmospheric pressure near the engine's air inlet is not 
within 5 kPa of the atmospheric pressure recorded 
at the time of the last engine map.
    (3) If the engine or emission-control system has undergone changes 
that might affect maximum torque performance. This includes changing the 
configuration of auxiliary work inputs and outputs.
    (4) If you capture an incomplete map on your first attempt or you do 
not complete a map within the specified time tolerance. You may repeat 
mapping as often as necessary to capture a complete map within the 
specified time.
    (b) Mapping variable-speed engines. Map variable-speed engines using 
the procedure in this paragraph (b). Note that under Sec.  1065.10(c) we 
may allow or require you to use ``other procedures'' if the specified 
procedure results in unrepresentative testing or if your engine cannot 
be tested using the specified procedure. If the engine has a user-
adjustable idle speed setpoint, you may set it to its minimum adjustable 
value for this mapping procedure and the resulting map may be used for 
any test, regardless of where it is set for running each test.
    (1) Record the atmospheric pressure.
    (2) Warm up the engine by operating it. We recommend operating the 
engine at any speed and at approximately 75% of its expected maximum 
power. Continue the warm-up until the engine coolant, block, or head 
absolute temperature is within 2% of its mean 
value for at least 2 min or until the engine thermostat controls engine 
temperature.
    (3) Operate the engine at its warm idle speed as follows:
    (i) For engines with a low-speed governor, set the operator demand 
to minimum, use the dynamometer or other loading device to target a 
torque of zero on the engine's primary output shaft, and allow the 
engine to govern the speed. Measure this warm idle speed; we recommend 
recording at least 30 values of speed and using the mean of those 
values.
    (ii) For engines without a low-speed governor, operate the engine at 
warm idle speed and zero torque on the engine's primary output shaft. 
You may use the dynamometer to target a torque of zero on the engine's 
primary output shaft, and manipulate the operator demand to control the 
speed to target the manufacturer-declared value for the lowest engine 
speed possible with minimum load (also known as manufacturer-declared 
warm idle speed). You may alternatively use the dynamometer to target 
the manufacturer-declared warm idle speed and manipulate the operator 
demand to control the torque on the engine's primary output shaft to 
zero.
    (iii) For variable-speed engines with or without a low-speed 
governor, if a nonzero idle torque is representative of

[[Page 151]]

in-use operation, you may use the dynamometer or operator demand to 
target the manufacturer-declared idle torque instead of targeting zero 
torque as specified in paragraphs (b)(3)(i) and (ii) of this section. 
Control speed as specified in paragraph (b)(3)(i) or (ii) of this 
section, as applicable. If you use this option for engines with a low-
speed governor to measure the warm idle speed with the manufacturer-
declared torque at this step, you may use this as the warm-idle speed 
for cycle generation as specified in paragraph (b)(6) of this section. 
However, if you identify multiple warm idle torques under paragraph 
(f)(4)(i) of this section, measure the warm idle speed at only one 
torque level for this paragraph (b)(3).
    (4) Operate the engine at the minimum mapped speed. A minimum mapped 
speed equal to (95 1)% of its warm idle speed 
determined in paragraph (b)(3) of this section may be used for any 
engine or test. A higher minimum mapped speed may be used if all the 
duty cycles that the engine is subject to have a minimum reference speed 
higher than the warm idle speed determined in paragraph (b)(3) of this 
section. In this case you may use a minimum mapped speed equal to (95 
1)% of the lowest minimum reference speed in all 
the duty cycles the engine is subject to. Set operator demand to maximum 
and control engine speed at this minimum mapped speed for at least 15 
seconds. Set operator demand to maximum and control engine speed at (95 
1)% of its warm idle speed determined in paragraph 
(b)(3)(i) of this section for at least 15 seconds.
    (5) Perform a continuous or discrete engine map as described in 
paragraphs (b)(5)(i) or (ii) of this section. A continuous engine map 
may be used for any engine. A discrete engine map may be used for 
engines subject only to steady-state duty cycles. Use linear 
interpolation between the series of points generated by either of these 
maps to determine intermediate torque values. Use the series of points 
generated by either of these maps to generate the power map as described 
in paragraph (e) of this section.
    (i) For continuous engine mapping, begin recording mean feedback 
speed and torque at 1 Hz or more frequently and increase speed at a 
constant rate such that it takes (4 to 6) min to sweep from the minimum 
mapped speed described in paragraphs (b)(4) of this section to the check 
point speed described in paragraph (b)(5)(iii) of this section. Use good 
engineering judgment to determine when to stop recording data to ensure 
that the sweep is complete. In most cases, this means that you can stop 
the sweep at any point after the power falls to 50% of the maximum 
value.
    (ii) For discrete engine mapping, select at least 20 evenly spaced 
setpoints from the minimum mapped speed described in paragraph (b)(4) of 
this section to the check point speed described in paragraph (b)(5)(iii) 
of this section. At each setpoint, stabilize speed and allow torque to 
stabilize. We recommend that you stabilize an engine for at least 15 
seconds at each setpoint and record the mean feedback speed and torque 
of the last (4 to 6) seconds. Record the mean speed and torque at each 
setpoint.
    (iii) The check point speed of the map is the highest speed above 
maximum power at which 50% of maximum power occurs. If this speed is 
unsafe or unachievable (e.g., for ungoverned engines or engines that do 
not operate at that point), use good engineering judgment to map up to 
the maximum safe speed or maximum achievable speed. For discrete 
mapping, if the engine cannot be mapped to the check point speed, make 
sure the map includes at least 20 points from 95% of warm idle to the 
maximum mapped speed. For continuous mapping, if the engine cannot be 
mapped to the check point speed, verify that the sweep time from 95% of 
warm idle to the maximum mapped speed is (4 to 6) min.
    (iv) Note that under Sec.  1065.10(c)(1) we may allow you to 
disregard portions of the map when selecting maximum test speed if the 
specified procedure would result in a duty cycle that does not represent 
in-use operation.
    (6) Determine warm high-idle speed for engines with a high-speed 
governor. You may skip this if the engine is not subject to transient 
testing with a duty cycle that includes reference speed values above 
100%. You may use

[[Page 152]]

a manufacturer-declared warm high-idle speed if the engine is 
electronically governed. For engines with a high-speed governor that 
regulates speed by disabling and enabling fuel or ignition at two 
manufacturer-specified speeds, declare the middle of this specified 
speed range as the warm high-idle speed. You may alternatively measure 
warm high-idle speed using the following procedure:
    (i) Run an operating point targeting zero torque.
    (A) Set operator demand to maximum and use the dynamometer to target 
zero torque on the engine's primary output shaft.
    (B) Wait for the engine governor and dynamometer to stabilize. We 
recommend that you stabilize for at least 15 seconds.
    (C) Record 1 Hz means of the feedback speed and torque for at least 
30 seconds. You may record means at a higher frequency as long as there 
are no gaps in the recorded data. For engines with a high-speed governor 
that regulates speed by disabling and enabling fuel or ignition, you may 
need to extend this stabilization period to include at least one 
disabling event at the higher speed and one enabling event at the lower 
speed.
    (D) Determine if the feedback speed is stable over the recording 
period. The feedback speed is considered stable if all the recorded 1 Hz 
means are within 2% of the mean feedback speed 
over the recording period. If the feedback speed is not stable because 
of the dynamometer, void the results and repeat measurements after 
making any necessary corrections. You may void and repeat the entire map 
sequence, or you may void and replace only the results for establishing 
warm high-idle speed; use good engineering judgment to warm-up the 
engine before repeating measurements.
    (E) If the feedback speed is stable, use the mean feedback speed 
over the recording period as the measured speed for this operating 
point.
    (F) If the feedback speed is not stable because of the engine, 
determine the mean as the value representing the midpoint between the 
observed maximum and minimum recorded feedback speed.
    (G) If the mean feedback torque over the recording period is within 
(0 1)% of Tmaxmapped, use the measured 
speed for this operating point as the warm high-idle speed. Otherwise, 
continue testing as described in paragraph (b)(6)(ii) of this section.
    (ii) Run a second operating point targeting a positive torque. 
Follow the same procedure in paragraphs (b)(6)(i)(A) through (F) of this 
section, except that the dynamometer is set to target a torque equal to 
the mean feedback torque over the recording period from the previous 
operating point plus 20% of Tmax mapped.
    (iii) Use the mean feedback speed and torque values from paragraphs 
(b)(6)(i) and (ii) of this section to determine the warm high-idle 
speed. If the two recorded speed values are the same, use that value as 
the warm high-idle-speed. Otherwise, use a linear equation passing 
through these two speed-torque points and extrapolate to solve for the 
speed at zero torque and use this speed intercept value as the warm 
high-idle speed.
    (iv) You may use a manufacturer-declared Tmax instead of 
the measured Tmax mapped. If you do this, you may also 
measure the warm high-idle speed as described in this paragraph (b)(6) 
before running the operating point and speed sweeps specified in 
paragraphs (b)(4) and (5) of this section.
    (7) For engines with a low-speed governor, if a nonzero idle torque 
is representative of in-use operation, operate the engine at warm idle 
with the manufacturer-declared idle torque. Set the operator demand to 
minimum, use the dynamometer to target the declared idle torque, and 
allow the engine to govern the speed. Measure this speed and use it as 
the warm idle speed for cycle generation in Sec.  1065.512. We recommend 
recording at least 30 values of speed and using the mean of those 
values. If you identify multiple warm idle torques under paragraph 
(f)(4)(i) of this section, measure the warm idle speed at each torque. 
You may map the idle governor at multiple load levels and use this map 
to determine the measured warm idle speed at the declared idle 
torque(s).
    (c) Negative torque mapping. If your engine is subject to a 
reference duty

[[Page 153]]

cycle that specifies negative torque values (i.e., engine motoring), 
generate a motoring torque curve by any of the following procedures:
    (1) Multiply the positive torques from your map by -40%. Use linear 
interpolation to determine intermediate values.
    (2) Map the amount of negative torque required to motor the engine 
by repeating paragraph (b) of this section with minimum operator demand, 
as applicable. You may start the negative torque map at either the 
minimum or maximum speed from paragraph (b) of this section.
    (3) Determine the amount of negative torque required to motor the 
engine at the following two points near the ends of the engine's speed 
range. Operate the engine at these two points at minimum operator 
demand. Use linear interpolation to determine intermediate values.
    (i) Low-speed point. For engines without a low-speed governor, 
determine the amount of negative torque at warm idle speed. For engines 
with a low-speed governor, motor the engine above warm idle speed so the 
governor is inactive and determine the amount of negative torque at that 
speed.
    (ii) High-speed point. For engines without a high-speed governor, 
determine the amount of negative torque at the maximum safe speed or the 
maximum representative speed. For engines with a high-speed governor, 
determine the amount of negative torque at a speed at or above 
nhi per Sec.  1065.610(c)(2).
    (4) For engines with an electric hybrid system, map the negative 
torque required to motor the engine and absorb any power delivered from 
the RESS by repeating paragraph (g)(2) of this section with minimum 
operator demand, stopping the sweep to discharge the RESS when the 
absolute instantaneous power measured from the RESS drops below the 
expected maximum absolute power from the RESS by more than 2% of total 
system maximum power (including engine motoring and RESS power) as 
determined from mapping the negative torque.
    (5) For engines with an electric hybrid system, map the negative 
torque required to motor the engine by repeating paragraph (b) of this 
section with minimum operator demand and a fully charged RESS or with 
the hybrid system disabled, such that it doesn't affect the motoring 
torque. You may start the negative torque map at either the minimum or 
maximum speed from paragraph (b) of this section.
    (d) Mapping constant-speed engines. Map constant-speed engines using 
the procedure in this paragraph (d). When testing without a motoring 
dynamometer (e.g., eddy-current or water-brake dynamometer or any device 
that is already installed on a vehicle, equipment, or vessel) operate 
these devices over the no-load operating points in the procedure as 
close to no-load as possible.
    (1) Record the atmospheric pressure.
    (2) Warm up the engine by operating it. We recommend operating the 
engine at approximately 75% of the engine's expected maximum power. 
Continue the warm-up until the engine coolant, block, or head absolute 
temperature is within 2% of its mean value for at 
least 2 min or until the engine thermostat controls engine temperature.
    (3) You may operate the engine with a production constant-speed 
governor or simulate a constant-speed governor by controlling engine 
speed with an operator demand control system described in Sec.  
1065.110. Use either isochronous or speed-droop governor operation, as 
appropriate.
    (4) With the governor or simulated governor controlling speed using 
operator demand, operate the engine at the no-load, or minimum 
achievable load, governed speed (at high speed, not low idle) for at 
least 15 seconds.
    (5) Record at 1 Hz the mean of feedback speed and torque. Use the 
dynamometer to increase torque at a constant rate. Unless the standard-
setting part specifies otherwise, complete the map such that it takes (2 
to 4) min to sweep from no-load governed speed to the speed below 
maximum mapped power at which the engine develops 90% of maximum mapped 
power. You may map your engine to lower speeds. Stop recording after you 
complete the sweep. Use this series of speeds and torques to generate 
the power map as described in paragraph (e) of this section.

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    (i) For constant-speed engines subject only to steady-state testing, 
you may perform an engine map by using a series of discrete torques. 
Select at least five evenly spaced torque setpoints from no-load to 80% 
of the manufacturer-declared test torque or to a torque derived from 
your published maximum power level if the declared test torque is 
unavailable. Starting at the 80% torque point, select setpoints in 2.5% 
or smaller intervals, stopping at the endpoint torque. The endpoint 
torque is defined as the first discrete mapped torque value greater than 
the torque at maximum observed power where the engine outputs 90% of the 
maximum observed power; or the torque when engine stall has been 
determined using good engineering judgment (i.e. sudden deceleration of 
engine speed while adding torque). You may continue mapping at higher 
torque setpoints. At each setpoint, allow torque and speed to stabilize. 
Record the mean feedback speed and torque at each setpoint. From this 
series of mean feedback speed and torque values, use linear 
interpolation to determine intermediate values. Use this series of mean 
feedback speeds and torques to generate the power map as described in 
paragraph (e) of this section.
    (ii) For any constant-speed engine, you may perform an engine map 
with a continuous torque sweep by continuing to record the mean feedback 
speed and torque at 1 Hz or more frequently. Use the dynamometer to 
increase torque. Increase the reference torque at a constant rate from 
no-load to the endpoint torque as defined in paragraph (d)(5)(i) of this 
section. You may continue mapping at higher torque setpoints. Unless the 
standard-setting part specifies otherwise, target a torque sweep rate 
equal to the manufacturer-declared test torque (or a torque derived from 
your published power level if the declared test torque is not known) 
divided by 180 seconds. Stop recording after you complete the sweep. 
Verify that the average torque sweep rate over the entire map is within 
7% of the target torque sweep rate. Use linear 
interpolation to determine intermediate values from this series of mean 
feedback speed and torque values. Use this series of mean feedback 
speeds and torques to generate the power map as described in paragraph 
(e) of this section.
    (iii) For any isochronous governed (0% speed droop) constant-speed 
engine, you may map the engine with two points as described in this 
paragraph (d)(5)(iii). After stabilizing at the no-load, or minimum 
achievable load, governed speed in paragraph (d)(4) of this section, 
record the mean feedback speed and torque. Continue to operate the 
engine with the governor or simulated governor controlling engine speed 
using operator demand, and control the dynamometer to target a speed of 
99.5% of the recorded mean no-load governed speed. Allow speed and 
torque to stabilize. Record the mean feedback speed and torque. Record 
the target speed. The absolute value of the speed error (the mean 
feedback speed minus the target speed) must be no greater than 0.1% of 
the recorded mean no-load governed speed. From this series of two mean 
feedback speed and torque values, use linear interpolation to determine 
intermediate values. Use this series of two mean feedback speeds and 
torques to generate a power map as described in paragraph (e) of this 
section. Note that the measured maximum test torque as determined in 
Sec.  1065.610(b)(1) will be the mean feedback torque recorded on the 
second point.
    (e) Power mapping. For all engines, create a power-versus-speed map 
by transforming torque and speed values to corresponding power values. 
Use the mean values from the recorded map data. Do not use any 
interpolated values. Multiply each torque by its corresponding speed and 
apply the appropriate conversion factors to arrive at units of power 
(kW). Interpolate intermediate power values between these power values, 
which were calculated from the recorded map data.
    (f) Measured and declared test speeds and torques. You must select 
test speeds and torques for cycle generation as required in this 
paragraph (f). ``Measured'' values are either directly measured during 
the engine mapping process or they are determined from the engine map. 
``Declared'' values are specified by the manufacturer. When both 
measured and declared values are available, you may use declared test

[[Page 155]]

speeds and torques instead of measured speeds and torques if they meet 
the criteria in this paragraph (f). Otherwise, you must use measured 
speeds and torques derived from the engine map.
    (1) Measured speeds and torques. Determine the applicable speeds and 
torques for the duty cycles you will run:
    (i) Measured maximum test speed for variable-speed engines according 
to Sec.  1065.610.
    (ii) Measured maximum test torque for constant-speed engines 
according to Sec.  1065.610.
    (iii) Measured ``A'', ``B'', and ``C'' speeds for variable-speed 
engines according to Sec.  1065.610.
    (iv) Measured intermediate speed for variable-speed engines 
according to Sec.  1065.610.
    (v) For variable-speed engines with a low-speed governor, measure 
warm idle speed according to Sec.  1065.510(b) and use this speed for 
cycle generation in Sec.  1065.512. For engines with no low-speed 
governor, instead use the manufacturer-declared warm idle speed.
    (2) Required declared speeds. You must declare the lowest engine 
speed possible with minimum load (i.e., manufacturer-declared warm idle 
speed). This is applicable only to variable-speed engines with no low-
speed governor. For engines with no low-speed governor, the declared 
warm idle speed is used for cycle generation in Sec.  1065.512. Declare 
this speed in a way that is representative of in-use operation. For 
example, if your engine is typically connected to an automatic 
transmission or a hydrostatic transmission, declare this speed at the 
idle speed at which your engine operates when the transmission is 
engaged.
    (3) Optional declared speeds. You may use declared speeds instead of 
measured speeds as follows:
    (i) You may use a declared value for maximum test speed for 
variable-speed engines if it is within (97.5 to 102.5) % of the 
corresponding measured value. You may use a higher declared speed if the 
length of the ``vector'' at the declared speed is within 2% of the 
length of the ``vector'' at the measured value. The term vector refers 
to the square root of the sum of normalized engine speed squared and the 
normalized full-load power (at that speed) squared, consistent with the 
calculations in Sec.  1065.610.
    (ii) You may use a declared value for intermediate, ``A'', ``B'', or 
``C'' speeds for steady-state tests if the declared value is within 
(97.5 to 102.5)% of the corresponding measured value.
    (iii) For electronically governed engines, you may use a declared 
warm high-idle speed for calculating the alternate maximum test speed as 
specified in Sec.  1065.610.
    (4) Required declared torques. If a nonzero idle or minimum torque 
is representative of in-use operation, you must declare the appropriate 
torque as follows:
    (i) For variable-speed engines, declare a warm idle torque that is 
representative of in-use operation. For example, if your engine is 
typically connected to an automatic transmission or a hydrostatic 
transmission, declare the torque that occurs at the idle speed at which 
your engine operates when the transmission is engaged. Use this value 
for cycle generation. You may use multiple warm idle torques and 
associated idle speeds in cycle generation for representative testing. 
For example, for cycles that start the engine and begin with idle, you 
may start a cycle in idle with the transmission in neutral with zero 
torque and later switch to a different idle with the transmission in 
drive with the Curb-Idle Transmission Torque (CITT). For variable-speed 
engines intended primarily for propulsion of a vehicle with an automatic 
transmission where that engine is subject to a transient duty cycle with 
idle operation, you must declare a CITT. We recommend that you specify 
CITT as a function of idle speed for engines with adjustable warm idle 
or enhanced-idle. You may specify a CITT based on typical applications 
at the mean of the range of idle speeds you specify at stabilized 
temperature conditions.
    (ii) For constant-speed engines, declare a warm minimum torque that 
is representative of in-use operation. For example, if your engine is 
typically connected to a machine that does not operate below a certain 
minimum torque, declare this torque and use it for cycle generation.

[[Page 156]]

    (5) Optional declared torques. (i) For variable-speed engines you 
may declare a maximum torque over the engine operating range. You may 
use the declared value for measuring warm high-idle speed as specified 
in this section.
    (ii) For constant-speed engines you may declare a maximum test 
torque. You may use the declared value for cycle generation if it is 
within (95 to 100) % of the measured value.
    (g) Mapping variable-speed engines with an electric hybrid system. 
Map variable-speed engines that include electric hybrid systems as 
described in this paragraph (g). You may ask to apply these provisions 
to other types of hybrid engines, consistent with good engineering 
judgment. However, do not use this procedure for engines used in hybrid 
vehicles where the hybrid system is certified as part of the vehicle 
rather than the engine. Follow the steps for mapping a variable-speed 
engine as given in paragraph (b)(5) of this section except as noted in 
this paragraph (g). You must generate one engine map with the hybrid 
system inactive as described in paragraph (g)(1) of this section, and a 
separate map with the hybrid system active as described in paragraph 
(g)(2) of this section. See the standard-setting part to determine how 
to use these maps. The map with the system inactive is typically used to 
generate steady-state duty cycles, but may also be used to generate 
transient cycles, such as those that do not involve engine motoring. 
This hybrid-inactive map is also used for generating the hybrid-active 
map. The hybrid-active map is typically used to generate transient duty 
cycles that involve engine motoring.
    (1) Prepare the engine for mapping by either deactivating the hybrid 
system or by operating the engine as specified in paragraph (b)(4) of 
this section and remaining at this condition until the rechargeable 
energy storage system (RESS) is depleted. Once the hybrid has been 
disabled or the RESS is depleted, perform an engine map as specified in 
paragraph (b)(5) of this section. If the RESS was depleted instead of 
deactivated, ensure that instantaneous power from the RESS remains less 
than 2% of the instantaneous measured power from the engine (or engine-
hybrid system) at all engine speeds.
    (2) The purpose of the mapping procedure in this paragraph (g) is to 
determine the maximum torque available at each speed, such as what might 
occur during transient operation with a fully charged RESS. Use one of 
the following methods to generate a hybrid-active map:
    (i) Perform an engine map by using a series of continuous sweeps to 
cover the engine's full range of operating speeds. Prepare the engine 
for hybrid-active mapping by ensuring that the RESS state of charge is 
representative of normal operation. Perform the sweep as specified in 
paragraph (b)(5)(i) of this section, but stop the sweep to charge the 
RESS when the power measured from the RESS drops below the expected 
maximum power from the RESS by more than 2% of total system power 
(including engine and RESS power). Unless good engineering judgment 
indicates otherwise, assume that the expected maximum power from the 
RESS is equal to the measured RESS power at the start of the sweep 
segment. For example, if the 3-second rolling average of total engine-
RESS power is 200 kW and the power from the RESS at the beginning of the 
sweep segment is 50 kW, once the power from the RESS reaches 46 kW, stop 
the sweep to charge the RESS. Note that this assumption is not valid 
where the hybrid motor is torque-limited. Calculate total system power 
as a 3-second rolling average of instantaneous total system power. After 
each charging event, stabilize the engine for 15 seconds at the speed at 
which you ended the previous segment with operator demand set to maximum 
before continuing the sweep from that speed. Repeat the cycle of 
charging, mapping, and recharging until you have completed the engine 
map. You may shut down the system or include other operation between 
segments to be consistent with the intent of this paragraph (g)(2)(i). 
For example, for systems in which continuous charging and discharging 
can overheat batteries to an extent that affects performance, you may 
operate the engine at zero power from the RESS for enough time after the 
system is recharged to allow

[[Page 157]]

the batteries to cool. Use good engineering judgment to smooth the 
torque curve to eliminate discontinuities between map intervals.
    (ii) Perform an engine map by using discrete speeds. Select map 
setpoints at intervals defined by the ranges of engine speed being 
mapped. From 95% of warm idle speed to 90% of the expected maximum test 
speed, select setpoints that result in a minimum of 13 equally spaced 
speed setpoints. From 90% to 110% of expected maximum test speed, select 
setpoints in equally spaced intervals that are nominally 2% of expected 
maximum test speed. Above 110% of expected maximum test speed, select 
setpoints based on the same speed intervals used for mapping from 95% 
warm idle speed to 90% maximum test speed. You may stop mapping at the 
highest speed above maximum power at which 50% of maximum power occurs. 
We refer to the speed at 50% power as the check point speed as described 
in paragraph (b)(5)(iii) of this section. Stabilize engine speed at each 
setpoint, targeting a torque value at 70% of peak torque at that speed 
without hybrid-assist. Make sure the engine is fully warmed up and the 
RESS state of charge is within the normal operating range. Snap the 
operator demand to maximum, operate the engine there for at least 10 
seconds, and record the 3-second rolling average feedback speed and 
torque at 1 Hz or higher. Record the peak 3-second average torque and 3-
second average speed at that point. Use linear interpolation to 
determine intermediate speeds and torques. Follow Sec.  1065.610(a) to 
calculate the maximum test speed. Verify that the measured maximum test 
speed falls in the range from 92 to 108% of the estimated maximum test 
speed. If the measured maximum test speed does not fall in this range, 
repeat the map using the measured value of maximum test speed.
    (h) Other mapping procedures. You may use other mapping procedures 
if you believe the procedures specified in this section are unsafe or 
unrepresentative for your engine. Any alternate techniques you use must 
satisfy the intent of the specified mapping procedures, which is to 
determine the maximum available torque at all engine speeds that occur 
during a duty cycle. Identify any deviations from this section's mapping 
procedures when you submit data to us.

[73 FR 37315, June 30, 2008, as amended at 73 FR 59330, Oct. 8, 2008; 75 
FR 23042, Apr. 30, 2010; 76 FR 57448, Sept. 15, 2011; 79 FR 23773, Apr. 
28, 2014; 81 FR 74169, Oct. 25, 2016; 86 FR 34545, June 29, 2021; 88 FR 
4676, Jan. 24, 2023]



Sec.  1065.512  Duty cycle generation.

    (a) Generate duty cycles according to this section if the standard-
setting part requires engine mapping to generate a duty cycle for your 
engine configuration. The standard-setting part generally defines 
applicable duty cycles in a normalized format. A normalized duty cycle 
consists of a sequence of paired values for speed and torque or for 
speed and power.
    (b) Transform normalized values of speed, torque, and power using 
the following conventions:
    (1) Engine speed for variable-speed engines. For variable-speed 
engines, normalized speed may be expressed as a percentage between warm 
idle speed, fnidle, and maximum test speed, 
fntest, or speed may be expressed by referring to a defined 
speed by name, such as ``warm idle,'' ``intermediate speed,'' or ``A,'' 
``B,'' or ``C'' speed. Section 1065.610 describes how to transform these 
normalized values into a sequence of reference speeds, fnref. 
Running duty cycles with negative or small normalized speed values near 
warm idle speed may cause low-speed idle governors to activate and the 
engine torque to exceed the reference torque even though the operator 
demand is at a minimum. In such cases, we recommend controlling the 
dynamometer so it gives priority to follow the reference torque instead 
of the reference speed and let the engine govern the speed. Note that 
the cycle-validation criteria in Sec.  1065.514 allow an engine to 
govern itself. This allowance permits you to test engines with enhanced-
idle devices and to simulate the effects of transmissions such as 
automatic transmissions. For example, an enhanced-idle device might be 
an idle speed value that is normally commanded only under cold-start 
conditions to quickly warm up the engine and aftertreatment devices. In 
this case, negative and very low normalized speeds will generate

[[Page 158]]

reference speeds below this higher enhanced-idle speed. You may do 
either of the following when using enhanced-idle devices:
    (i) Control the dynamometer so it gives priority to follow the 
reference torque, controlling the operator demand so it gives priority 
to follow reference speed and let the engine govern the speed when the 
operator demand is at minimum.
    (ii) While running an engine where the ECM broadcasts an enhanced-
idle speed that is above the denormalized speed, use the broadcast speed 
as the reference speed. Use these new reference points for duty-cycle 
validation. This does not affect how you determine denormalized 
reference torque in paragraph (b)(2) of this section.
    (iii) If an ECM broadcast signal is not available, perform one or 
more practice cycles to determine the enhanced-idle speed as a function 
of cycle time. Generate the reference cycle as you normally would but 
replace any reference speed that is lower than the enhanced-idle speed 
with the enhanced-idle speed. This does not affect how you determine 
denormalized reference torque in paragraph (b)(2) of this section.
    (2) Engine torque for variable-speed engines. For variable-speed 
engines, normalized torque is expressed as a percentage of the mapped 
torque at the corresponding reference speed. Section 1065.610 describes 
how to transform normalized torques into a sequence of reference 
torques, Tref. Section 1065.610 also describes special 
requirements for modifying transient duty cycles for variable-speed 
engines intended primarily for propulsion of a vehicle with an automatic 
transmission. Section 1065.610 also describes under what conditions you 
may command Tref greater than the reference torque you calculated from a 
normalized duty cycle, which permits you to command Tref 
values that are limited by a declared minimum torque. For any negative 
torque commands, command minimum operator demand and use the dynamometer 
to control engine speed to the reference speed, but if reference speed 
is so low that the idle governor activates, we recommend using the 
dynamometer to control torque to zero, CITT, or a declared minimum 
torque as appropriate. Note that you may omit power and torque points 
during motoring from the cycle-validation criteria in Sec.  1065.514. 
Also, use the maximum mapped torque at the minimum mapped speed as the 
maximum torque for any reference speed at or below the minimum mapped 
speed.7
    (3) Engine torque for constant-speed engines. For constant-speed 
engines, normalized torque is expressed as a percentage of maximum test 
torque, Ttest. Section 1065.610 describes how to transform 
normalized torques into a sequence of reference torques, 
Tref. Section 1065.610 also describes under what conditions 
you may command Tref greater than the reference torque you 
calculated from the normalized duty cycle. This provision permits you to 
command Tref values that are limited by a declared minimum 
torque.
    (4) Engine power. For all engines, normalized power is expressed as 
a percentage of mapped power at maximum test speed, fntest, 
unless otherwise specified by the standard-setting part. Section 
1065.610 describes how to transform these normalized values into a 
sequence of reference powers, Pref. Convert these reference 
powers to corresponding torques for operator demand and dynamometer 
control. Use the reference speed associated with each reference power 
point for this conversion. As with cycles specified with % torque, issue 
torque commands more frequently and linearly interpolate between these 
reference torque values generated from cycles with % power.
    (5) Ramped-modal cycles. For ramped-modal cycles, generate reference 
speed and torque values at 1 Hz and use this sequence of points to run 
the cycle and validate it in the same manner as with a transient cycle. 
During the transition between modes, linearly ramp the denormalized 
reference speed and torque values between modes to generate reference 
points at 1 Hz. Do not linearly ramp the normalized reference torque 
values between modes and then denormalize them. Do not linearly ramp 
normalized or denormalized reference power points. These cases will 
produce nonlinear torque ramps in the denormalized reference torques. If 
the speed and torque ramp runs through a point above the engine's torque 
curve,

[[Page 159]]

continue to command the reference torques and allow the operator demand 
to go to maximum. Note that you may omit power and either torque or 
speed points from the cycle-validation criteria under these conditions 
as specified in Sec.  1065.514.
    (c) For variable-speed engines, command reference speeds and torques 
sequentially to perform a duty cycle. Issue speed and torque commands at 
a frequency of at least 5 Hz for transient cycles and at least 1 Hz for 
steady-state cycles (i.e., discrete-mode and ramped-modal). Linearly 
interpolate between the 1 Hz reference values specified in the standard-
setting part to determine more frequently issued reference speeds and 
torques. During an emission test, record the feedback speeds and torques 
at a frequency of at least 5 Hz for transient cycles and at least 1 Hz 
for steady-state cycles. For transient cycles, you may record the 
feedback speeds and torques at lower frequencies (as low as 1 Hz) if you 
record the average value over the time interval between recorded values. 
Calculate the average values based on feedback values updated at a 
frequency of at least 5 Hz. Use these recorded values to calculate 
cycle-validation statistics and total work.
    (d) For constant-speed engines, operate the engine with the same 
production governor you used to map the engine in Sec.  1065.510 or 
simulate the in-use operation of a governor the same way you simulated 
it to map the engine in Sec.  1065.510. Command reference torque values 
sequentially to perform a duty cycle. Issue torque commands at a 
frequency of at least 5 Hz for transient cycles and at least 1 Hz for 
steady-state cycles (i.e., discrete-mode, ramped-modal). Linearly 
interpolate between the 1 Hz reference values specified in the standard-
setting part to determine more frequently issued reference torque 
values. During an emission test, record the feedback speeds and torques 
at a frequency of at least 5 Hz for transient cycles and at least 1 Hz 
for steady-state cycles. For transient cycles, you may record the 
feedback speeds and torques at lower frequencies (as low as 1 Hz) if you 
record the average value over the time interval between recorded values. 
Calculate the average values based on feedback values updated at a 
frequency of at least 5 Hz. Use these recorded values to calculate 
cycle-validation statistics and total work.
    (e) You may perform practice duty cycles with the test engine to 
optimize operator demand and dynamometer controls to meet the cycle-
validation criteria specified in Sec.  1065.514.

[73 FR 37317, June 30, 2008, as amended at 79 FR 23774, Apr. 28, 2014; 
86 FR 34546, June 29, 2021; 88 FR 4678, Jan. 24, 2023]



Sec.  1065.514  Cycle-validation criteria for operation over specified duty cycles.

    Validate the execution of your duty cycle according to this section 
unless the standard-setting part specifies otherwise. This section 
describes how to determine if the engine's operation during the test 
adequately matched the reference duty cycle. This section applies only 
to speed, torque, and power from the engine's primary output shaft. 
Other work inputs and outputs are not subject to cycle-validation 
criteria. You must compare the original reference duty cycle points 
generated as described in Sec.  1065.512 to the corresponding feedback 
values recorded during the test. You may compare reference duty cycle 
points recorded during the test to the corresponding feedback values 
recorded during the test as long as the recorded reference values match 
the original points generated in Sec.  1065.512. The number of points in 
the validation regression are based on the number of points in the 
original reference duty cycle generated in Sec.  1065.512. For example 
if the original cycle has 1199 reference points at 1 Hz, then the 
regression will have up to 1199 pairs of reference and feedback values 
at the corresponding moments in the test. The feedback speed and torque 
signals may be filtered--either in real-time while the test is run or 
afterward in the analysis program. Any filtering that is used on the 
feedback signals used for cycle validation must also be used for 
calculating work. Feedback signals for control loops may use different 
filtering.
    (a) Testing performed by EPA. Our tests must meet the specifications 
of paragraph (f) of this section, unless we

[[Page 160]]

determine that failing to meet the specifications is related to engine 
performance rather than to shortcomings of the dynamometer or other 
laboratory equipment.
    (b) Testing performed by manufacturers. Emission tests that meet the 
specifications of paragraph (f) of this section satisfy the standard-
setting part's requirements for duty cycles. You may ask to use a 
dynamometer or other laboratory equipment that cannot meet those 
specifications. We will approve your request as long as using the 
alternate equipment does not adversely affect your ability to show 
compliance with the applicable emission standards.
    (c) Time-alignment. Because time lag between feedback values and the 
reference values may bias cycle-validation results, you may advance or 
delay the entire sequence of feedback engine speed and torque pairs to 
synchronize them with the reference sequence. If you advance or delay 
feedback signals for cycle validation, you must make the same adjustment 
for calculating work. You may use linear interpolation between 
successive recorded feedback signals to time shift an amount that is a 
fraction of the recording period.
    (d) Omitting additional points. Besides engine cranking, you may 
omit additional points from cycle-validation statistics as described in 
the following table:

Table 1 to Paragraph (d) of Sec.   1065.514--Permissible Criteria for Omitting Points From Duty-Cycle Regression
                                                   Statistics
----------------------------------------------------------------------------------------------------------------
  When operator demand is at its . . .         you may omit . . .                       if . . .
----------------------------------------------------------------------------------------------------------------
                For reference duty cycles that are specified in terms of speed and torque (f, T)
----------------------------------------------------------------------------------------------------------------
minimum.................................  power and torque...........  Tref < 0% (motoring).
minimum.................................  power and speed............  fnref = 0% (idle speed) and Tref = 0%
                                                                        (idle torque) and Tref-(2% [middot] Tmax
                                                                        mapped) < T < Tref + (2% [middot] Tmax
                                                                        mapped).
minimum.................................  power and speed............  fnref < enhanced-idle speed \a\ and Tref
                                                                        > 0%.
minimum.................................  power and either torque or   fn > fnref or T > Tref but not if fn >
                                           speed.                       (fnref [middot] 102%) and T > Tref + (2%
                                                                        [middot] Tmax mapped).
maximum.................................  power and either torque or   fn < fnref or T < Tref but not if fn <
                                           speed.                       (fnref [middot] 98%) and T < Tref-(2%
                                                                        [middot] Tmax mapped).
----------------------------------------------------------------------------------------------------------------
                 For reference duty cycles that are specified in terms of speed and power (f, P)
----------------------------------------------------------------------------------------------------------------
minimum.................................  power and torque...........  Pref < 0% (motoring).
minimum.................................  power and speed............  fnref = 0% (idle speed) and Pref = 0%
                                                                        (idle power) and Pref-(2% [middot] Pmax
                                                                        mapped) < P < Pref + (2% [middot] Pmax
                                                                        mapped).
minimum.................................  power and either torque or   fn > fnref or P > Pref but not if fn >
                                           speed.                       (fnref [middot] 102%) and P > Pref + (2%
                                                                        [middot] Pmax mapped).
maximum.................................  power and either torque or   fn < fnref or P < Pref but not if fn <
                                           speed.                       (fnref [middot] 98%) and P < Pref-(2%
                                                                        [middot] Pmax mapped).
----------------------------------------------------------------------------------------------------------------
\a\ Determine enhanced-idle speed from ECM broadcast or a practice cycle.

    (e) Statistical parameters. Use the remaining points to calculate 
regression statistics for a floating intercept as described in Sec.  
1065.602. Round calculated regression statistics to the same number of 
significant digits as the criteria to which they are compared. Refer to 
Table 2 of this section for the default criteria and refer to the 
standard-setting part to determine if there are other criteria for your 
engine. Calculate the following regression statistics:
    (1) Slopes for feedback speed, a1fn, feedback torque, 
a1T, and feedback power a1P.
    (2) Intercepts for feedback speed, a0fn, feedback torque, 
a0T, and feedback power a0P.
    (3) Standard error of the estimate for feedback speed, SEEfn, 
feedback torque, SEET, and feedback power SEEP.
    (4) Coefficients of determination for feedback speed, 
r\2\fn, feedback torque, r\2\T, and feedback power 
r\2\P.
    (f) Cycle-validation criteria. Unless the standard-setting part 
specifies otherwise, use the following criteria to validate a duty 
cycle:

[[Page 161]]

    (1) For variable-speed engines, apply all the statistical criteria 
in Table 2 of this section.
    (2) For constant-speed engines, apply only the statistical criteria 
for torque in Table 2 of this section.
    (3) For discrete-mode steady-state testing, apply cycle-validation 
criteria by treating the sampling periods from the series of test modes 
as a continuous sampling period, analogous to ramped-modal testing and 
apply statistical criteria as described in paragraph (f)(1) or (2) of 
this section. Note that if the gaseous and particulate test intervals 
are different periods of time, separate validations are required for the 
gaseous and particulate test intervals. Table 2 follows:

               Table 2 of Sec.   1065.514--Default Statistical Criteria for Validating Duty Cycles
----------------------------------------------------------------------------------------------------------------
              Parameter                         Speed                    Torque                   Power
----------------------------------------------------------------------------------------------------------------
Slope, a1............................  0.950 <= a1 <= 1.030...  0.830 <= a1 <= 1.030...  0.830 <= a1 <= 1.030.
Absolute value of intercept,           <= 10% of warm idle....  <= 2% of maximum mapped  <= 2% of maximum mapped
 [verbarlm]a0[verbarlm].                                         torque.                  power.
Standard error of the estimate, SEE..  <= 5% of maximum test    <= 10% of maximum        <= 10% of maximum
                                        speed.                   mapped torque.           mapped power.
Coefficient of determination, r2.....  = 0.970.....  = 0.850.....  = 0.910.
----------------------------------------------------------------------------------------------------------------


[73 FR 37318, June 30, 2008, as amended at 73 FR 59330, Oct. 8, 2008; 75 
FR 23042, Apr. 30, 2010; 76 FR 57450, Sept. 15, 2011; 86 FR 34546, June 
29, 2021; 88 FR 4678, Jan. 24, 2023]



Sec.  1065.516  Sample system decontamination and preconditioning.

    This section describes how to manage the impact of sampling system 
contamination on emission measurements. Use good engineering judgment to 
determine if you should decontaminate and precondition your sampling 
system. Contamination occurs when a regulated pollutant accumulates in 
the sample system in a high enough concentration to cause release during 
emission tests. Hydrocarbons and PM are generally the only regulated 
pollutants that contaminate sample systems. Note that although this 
section focuses on avoiding excessive contamination of sampling systems, 
you must also use good engineering judgment to avoid loss of sample to a 
sampling system that is too clean. The goal of decontamination is not to 
perfectly clean the sampling system, but rather to achieve equilibrium 
between the sampling system and the exhaust so emission components are 
neither lost to nor entrained from the sampling system.
    (a) You may perform contamination checks as follows to determine if 
decontamination is needed:
    (1) For dilute exhaust sampling systems, measure hydrocarbon and PM 
emissions by sampling with the CVS dilution air turned on, without an 
engine connected to it.
    (2) For raw analyzers and systems that collect PM samples from raw 
exhaust, measure hydrocarbon and PM emissions by sampling purified air 
or nitrogen.
    (3) When calculating zero emission levels, apply all applicable 
corrections, including initial THC contamination and diluted (CVS) 
exhaust background corrections.
    (4) Sampling systems are considered contaminated if either of the 
following conditions applies:
    (i) The hydrocarbon emission level exceeds 2% of the flow-weighted 
mean concentration expected at the HC standard.
    (ii) The PM emission level exceeds 5% of the level expected at the 
standard and exceeds 20 [micro]g on a 47 mm PTFE membrane filter.
    (b) To precondition or decontaminate sampling systems, use the 
following recommended procedure or select a different procedure using 
good engineering judgment:
    (1) Start the engine and use good engineering judgment to operate it 
at a condition that generates high exhaust temperatures at the sample 
probe inlet.
    (2) Operate any dilution systems at their expected flow rates. 
Prevent aqueous condensation in the dilution systems.

[[Page 162]]

    (3) Operate any PM sampling systems at their expected flow rates.
    (4) Sample PM for at least 10 min using any sample media. You may 
change sample media at any time during this process and you may discard 
them without weighing them.
    (5) You may purge any gaseous sampling systems that do not require 
decontamination during this procedure.
    (6) You may conduct calibrations or verifications on any idle 
equipment or analyzers during this procedure.
    (c) If your sampling system is still contaminated following the 
procedures specified in paragraph (b) of this section, you may use more 
aggressive procedures to decontaminate the sampling system, as long as 
the decontamination does not cause the sampling system to be cleaner 
than an equilibrium condition such that artificially low emission 
measurements may result.

[79 FR 23774, Apr. 28, 2014]



Sec.  1065.518  Engine preconditioning.

    (a) This section applies for engines where measured emissions are 
affected by prior operation, such as with a diesel engine that relies on 
urea-based selective catalytic reduction. Note that Sec.  1065.520(e) 
allows you to run practice duty cycles before the emission test; this 
section recommends how to do this for the purpose of preconditioning the 
engine. Follow the standard-setting part if it specifies a different 
engine preconditioning procedure.
    (b) The intent of engine preconditioning is to manage the 
representativeness of emissions and emission controls over the duty 
cycle and to reduce bias.
    (c) This paragraph (c) specifies the engine preconditioning 
procedures for different types of duty cycles. You must identify the 
amount of preconditioning before starting to precondition. You must run 
the predefined amount of preconditioning. You may measure emissions 
during preconditioning. You may not abort an emission test sequence 
based on emissions measured during preconditioning. For confirmatory 
testing, you may ask us to run more preconditioning cycles than we 
specify in this paragraph (c); we will agree to this only if you show 
that additional preconditioning cycles are required to meet the intent 
of paragraph (b) of this section, for example, due to the effect of DPF 
regeneration on NH3 storage in the SCR catalyst. Perform 
preconditioning as follows, noting that the specific cycles for 
preconditioning are the same ones that apply for emission testing:
    (1) Cold-start transient cycle. Precondition the engine by running 
at least one hot-start transient cycle. We will precondition your engine 
by running two hot-start transient cycles. Immediately after completing 
each preconditioning cycle, shut down the engine and complete the 
engine-off soak period. Immediately after completing the last 
preconditioning cycle, shut down the engine and begin the cold soak as 
described in Sec.  1065.530(a)(1).
    (2) Hot-start transient cycle. Precondition the engine by running at 
least one hot-start transient cycle. We will precondition your engine by 
running two hot-start transient cycles. Immediately after completing 
each preconditioning cycle, shut down the engine, then start the next 
cycle (including the emission test) as soon as practical. For any repeat 
cycles, start the next cycle within 60 seconds after completing the last 
preconditioning cycle (this is optional for manufacturer testing).
    (3) Hot-running transient cycle. Precondition the engine by running 
at least one hot-running transient cycle. We will precondition your 
engine by running two hot-running transient cycles. Do not shut down the 
engine between cycles. Immediately after completing each preconditioning 
cycle, start the next cycle (including the emission test) as soon as 
practical. For any repeat cycles, start the next cycle within 60 seconds 
after completing the last preconditioning cycle (this is optional for 
manufacturer testing). See Sec.  1065.530(a)(1)(iii) for additional 
instructions if the cycle begins and ends under different operating 
conditions.
    (4) Discrete-mode cycle for steady-state testing. Precondition the 
engine at the same operating condition as the next test mode, unless the 
standard-setting part specifies otherwise. We will precondition your 
engine by running it for at least five minutes before sampling.

[[Page 163]]

    (5) Ramped-modal cycle for steady-state testing. Precondition the 
engine by running at least the second half of the ramped-modal cycle, 
based on the number of test modes. For example, for the five-mode cycle 
specified in 40 CFR 1039.505(b)(1), the second half of the cycle 
consists of modes three through five. We will precondition your engine 
by running one complete ramped-modal cycle. Do not shut down the engine 
between cycles. Immediately after completing each preconditioning cycle, 
start the next cycle (including the emission test) as soon as practical. 
For any repeat cycles, start the next cycle within 60 seconds after 
completing the last preconditioning cycle. See Sec.  1065.530(a)(1)(iii) 
for additional instructions if the cycle begins and ends under different 
operating conditions.
    (d) You may conduct calibrations or verifications on any idle 
equipment or analyzers during engine preconditioning.

[79 FR 23774, Apr. 28, 2014]



Sec.  1065.520  Pre-test verification procedures and pre-test data collection.

    (a) For tests in which you measure PM emissions, follow the 
procedures for PM sample preconditioning and tare weighing according to 
Sec.  1065.590.
    (b) Unless the standard-setting part specifies different tolerances, 
verify at some point before the test that ambient conditions are within 
the tolerances specified in this paragraph (b). For purposes of this 
paragraph (b), ``before the test'' means any time from a point just 
prior to engine starting (excluding engine restarts) to the point at 
which emission sampling begins.
    (1) Ambient temperature of (20 to 30) [deg]C. See Sec.  1065.530(j) 
for circumstances under which ambient temperatures must remain within 
this range during the test.
    (2) Atmospheric pressure of (80.000 to 103.325) kPa and within 
5 kPa of the value recorded at the time of the 
last engine map. You are not required to verify atmospheric pressure 
prior to a hot start test interval for testing that also includes a cold 
start.
    (3) Dilution air conditions as specified in Sec.  1065.140, except 
in cases where you preheat your CVS before a cold start test. We 
recommend verifying dilution air conditions just prior to the start of 
each test interval.
    (c) You may test engines at any intake-air humidity, and we may test 
engines at any intake-air humidity.
    (d) Verify that auxiliary-work inputs and outputs are configured as 
they were during engine mapping, as described in Sec.  1065.510(a).
    (e) You may perform a final calibration of the speed, torque, and 
proportional-flow control systems, which may include performing practice 
duty cycles (or portions of duty cycles). This may be done in 
conjunction with the preconditioning in Sec.  1065.518.
    (f) Verify the amount of nonmethane hydrocarbon contamination in the 
exhaust and background HC sampling systems within 8 hours before the 
start of the first test interval of each duty-cycle sequence for 
laboratory tests. You may verify the contamination of a background HC 
sampling system by reading the last bag fill and purge using zero gas. 
For any NMHC measurement system that involves separately measuring 
CH4 and subtracting it from a THC measurement or for any 
CH4 measurement system that uses an NMC, verify the amount of 
THC contamination using only the THC analyzer response. There is no need 
to operate any separate CH4 analyzer for this verification; 
however, you may measure and correct for THC contamination in the 
CH4 sample path for the cases where NMHC is determined by 
subtracting CH4 from THC or, where CH4 is 
determined, using an NMC as configured in Sec.  1065.365(d), (e), and 
(f); and using the calculations in Sec.  1065.660(b)(2). Perform this 
verification as follows:
    (1) Select the HC analyzer range for measuring the flow-weighted 
mean concentration expected at the HC standard.
    (2) Zero the HC analyzer at the analyzer zero or sample port. Note 
that FID zero and span balance gases may be any combination of purified 
air or purified nitrogen that meets the specifications of Sec.  
1065.750. We recommend FID analyzer zero and span gases that contain 
approximately the flow-weighted mean concentration of O2 
expected during testing.

[[Page 164]]

    (3) Span the HC analyzer using span gas introduced at the analyzer 
span or sample port. Span on a carbon number basis of one 
(C1). For example, if you use a C3H8 
span gas of concentration 200 [micro]mol/mol, span the FID to respond 
with a value of 600 [micro]mol/mol.
    (4) Overflow zero gas at the HC probe inlet or into a tee near the 
probe outlet.
    (5) Measure the THC concentration in the sampling and background 
systems as follows:
    (i) For continuous sampling, record the mean THC concentration as 
overflow zero gas flows.
    (ii) For batch sampling, fill the sample medium (e.g., bag) and 
record its mean THC concentration.
    (iii) For the background system, record the mean THC concentration 
of the last fill and purge.
    (6) Record this value as the initial THC concentration, 
xTHC[THC-FID]init, and use it to correct measured values as 
described in Sec.  1065.660.
    (7) You may correct the measured initial THC concentration for drift 
as follows:
    (i) For batch and continuous HC analyzers, after determining the 
initial THC concentration, flow zero gas to the analyzer zero or sample 
port. When the analyzer reading is stable, record the mean analyzer 
value.
    (ii) Flow span gas to the analyzer span or sample port. When the 
analyzer reading is stable, record the mean analyzer value.
    (iii) Use mean analyzer values from paragraphs (f)(2), (f)(3), 
(f)(7)(i), and (f)(7)(ii) of this section to correct the initial THC 
concentration recorded in paragraph (f)(6) of this section for drift, as 
described in Sec.  1065.550.
    (8) If any of the xTHC[THC-FID]init values exceed the 
greatest of the following values, determine the source of the 
contamination and take corrective action, such as purging the system 
during an additional preconditioning cycle or replacing contaminated 
portions:
    (i) 2% of the flow-weighted mean concentration expected at the HC 
(THC or NMHC) standard.
    (ii) 2% of the flow-weighted mean concentration of HC (THC or NMHC) 
measured during testing.
    (iii) 2 [micro]mol/mol.
    (9) If corrective action does not resolve the deficiency, you may 
request to use the contaminated system as an alternate procedure under 
Sec.  1065.10.

[79 FR 23775, Apr. 28, 2014]



Sec.  1065.525  Engine starting, restarting, and shutdown.

    (a) For test intervals that require emission sampling during engine 
starting, start the engine using one of the following methods:
    (1) Start the engine as recommended in the owners manual using a 
production starter motor or air-start system and either an adequately 
charged battery, a suitable power supply, or a suitable compressed air 
source.
    (2) Use the dynamometer to start the engine. To do this, motor the 
engine within 25% of its typical in-use cranking 
speed. Stop cranking within 1 second of starting the engine.
    (3) In the case of hybrid engines, activate the system such that the 
engine will start when its control algorithms determine that the engine 
should provide power instead of or in addition to power from the RESS. 
Unless we specify otherwise, engine starting throughout this part 
generally refers to this step of activating the system on hybrid 
engines, whether or not that causes the engine to start running.
    (b) If the engine does not start after 15 seconds of cranking, stop 
cranking and determine why the engine failed to start, unless the owners 
manual or the service-repair manual describes the longer cranking time 
as normal.
    (c) Respond to engine stalling with the following steps:
    (1) If the engine stalls during warm-up before emission sampling 
begins, restart the engine and continue warm-up.
    (2) If the engine stalls during preconditioning before emission 
sampling begins, restart the engine and restart the preconditioning 
sequence.
    (3) Void the entire test if the engine stalls at any time after 
emission sampling begins, except as described in Sec.  1065.526. If you 
do not void the entire test, you must void the individual test mode or 
test interval in which the engine stalls.

[[Page 165]]

    (d) Shut down the engine according to the manufacturer's 
specifications.

[73 FR 37320, June 30, 2008, as amended at 75 FR 68463, Nov. 8, 2010; 76 
FR 57451, Sept. 15, 2011]



Sec.  1065.526  Repeating of void modes or test intervals.

    (a) Test modes and test intervals can be voided because of 
instrument malfunction, engine stalling, emissions exceeding instrument 
ranges, and other unexpected deviations from the specified procedures. 
This section specifies circumstances for which a test mode or test 
interval can be repeated without repeating the entire test.
    (b) This section is intended to result in replicate test modes and 
test intervals that are identical to what would have occurred if the 
cause of the voiding had not occurred. It does not allow you to repeat 
test modes or test intervals in any circumstances that would be 
inconsistent with good engineering judgment. For example, the procedures 
specified here for repeating a mode or interval may not apply for 
certain engines that include hybrid energy storage features or emission 
controls that involve physical or chemical storage of pollutants. This 
section applies for circumstances in which emission concentrations 
exceed the analyzer range only if it is due to operator error or 
analyzer malfunction. It does not apply for circumstances in which the 
emission concentrations exceed the range because they were higher than 
expected.
    (c) If one of the modes of a discrete-mode duty cycle is voided 
while running the duty cycle as provided in this section, you may void 
the results for that individual mode and continue the duty cycle as 
follows:
    (1) If the engine has stalled or been shut down, restart the engine.
    (2) Use good engineering judgment to restart the duty cycle using 
the appropriate steps in Sec.  1065.530(b).
    (3) Stabilize the engine by operating it at the mode at which the 
duty cycle was interrupted and continue with the duty cycle as specified 
in the standard-setting part.
    (d) If an individual mode of a discrete-mode duty cycle sequence is 
voided after running the full duty cycle, you may void results for that 
mode and repeat testing for that mode as follows:
    (1) Use good engineering judgment to restart the test sequence using 
the appropriate steps in Sec.  1065.530(b).
    (2) Stabilize the engine by operating it at that mode.
    (3) Sample emissions over an appropriate test interval.
    (4) If you sampled gaseous and PM emissions over separate test 
intervals for a voided mode, you must void both test intervals and 
repeat sampling of both gaseous and PM emissions for that mode.
    (e) If a transient or ramped-modal cycle test interval is voided as 
provided in this section, you may repeat the test interval as follows:
    (1) Use good engineering judgment to restart (as applicable) and 
precondition the engine to the same condition as would apply for normal 
testing. This may require you to complete the voided test interval. For 
example, you may generally repeat a hot-start test of a heavy-duty 
highway engine after completing the voided hot-start test and allowing 
the engine to soak for 20 minutes.
    (2) Complete the remainder of the test according to the provisions 
in this subpart.
    (f) Keep records from the voided test mode or test interval in the 
same manner as required for unvoided tests.

[79 FR 23776, Apr. 28, 2014]



Sec.  1065.530  Emission test sequence.

    (a) Time the start of testing as follows:
    (1) Perform one of the following if you precondition the engine as 
described in Sec.  1065.518:
    (i) For cold-start duty cycles, shut down the engine. Unless the 
standard-setting part specifies that you may only perform a natural 
engine cooldown, you may perform a forced engine cooldown. Use good 
engineering judgment to set up systems to send cooling air across the 
engine, to send cool oil through the engine lubrication system, to 
remove heat from coolant through the engine cooling system, and to 
remove heat from any exhaust aftertreatment systems. In the case of a 
forced aftertreatment cooldown, good engineering judgment would indicate

[[Page 166]]

that you not start flowing cooling air until the aftertreatment system 
has cooled below its catalytic activation temperature. For platinum-
group metal catalysts, this temperature is about 200 [deg]C. Once the 
aftertreatment system has naturally cooled below its catalytic 
activation temperature, good engineering judgment would indicate that 
you use clean air with a temperature of at least 15 [deg]C, and direct 
the air through the aftertreatment system in the normal direction of 
exhaust flow. Do not use any cooling procedure that results in 
unrepresentative emissions (see Sec.  1065.10(c)(1)). You may start a 
cold-start duty cycle when the temperatures of an engine's lubricant, 
coolant, and aftertreatment systems are all between (20 and 30) [deg]C.
    (ii) For hot-start emission measurements, shut down the engine 
immediately after completing the last preconditioning cycle. For any 
repeat cycles, start the hot-start transient emission test within 60 
seconds after completing the last preconditioning cycle (this is 
optional for manufacturer testing).
    (iii) For testing that involves hot-stabilized emission 
measurements, such as any steady-state testing with a ramped-modal 
cycle, start the hot-stabilized emission test within 60 seconds after 
completing the last preconditioning cycle (the time between cycles is 
optional for manufacturer testing). If the hot-stabilized cycle begins 
and ends with different operating conditions, add a linear transition 
period of 20 seconds between hot-stabilized cycles where you linearly 
ramp the (denormalized) reference speed and torque values over the 
transition period. See Sec.  1065.501(c)(2)(i) for discrete-mode cycles.
    (2) If you do not precondition the engine as described in Sec.  
1065.518, perform one of the following:
    (i) For cold-start duty cycles, prepare the engine according to 
paragraph (a)(1)(i) of this section.
    (ii) For hot-start duty cycles, first operate the engine at any 
speed above peak-torque speed and at (65 to 85) % of maximum mapped 
power until either the engine coolant, block, or head absolute 
temperature is within 2% of its mean value for at 
least 2 min or until the engine thermostat controls engine temperature. 
Shut down the engine. Start the duty cycle within 20 min of engine 
shutdown.
    (iii) For testing that involves hot-stabilized emission 
measurements, bring the engine either to warm idle or the first 
operating point of the duty cycle. Start the test within 10 min of 
achieving temperature stability. Determine temperature stability as the 
point at which the engine thermostat controls engine temperature or as 
the point at which measured operating temperature has stayed within 
2% of the mean value for at least 2 min based on 
the following parameters:
    (A) Engine coolant or block or head absolute temperatures for water-
cooled engines.
    (B) Oil sump absolute temperature for air-cooled engines with an oil 
sump.
    (C) Cylinder head absolute temperature or exhaust gas temperature 
for air-cooled engines with no oil sump.
    (b) Take the following steps before emission sampling begins:
    (1) For batch sampling, connect clean storage media, such as 
evacuated bags or tare-weighed filters.
    (2) Start all measurement instruments according to the instrument 
manufacturer's instructions and using good engineering judgment.
    (3) Start dilution systems, sample pumps, cooling fans, and the 
data-collection system.
    (4) Pre-heat or pre-cool heat exchangers in the sampling system to 
within their operating temperature tolerances for a test.
    (5) Allow heated or cooled components such as sample lines, filters, 
chillers, and pumps to stabilize at their operating temperatures.
    (6) Verify that there are no significant vacuum-side leaks according 
to Sec.  1065.345.
    (7) Adjust the sample flow rates to desired levels, using bypass 
flow, if desired.
    (8) Zero or re-zero any electronic integrating devices, before the 
start of any test interval.
    (9) Select gas analyzer ranges. You may automatically or manually 
switch gas analyzer ranges during a test only if switching is performed 
by changing

[[Page 167]]

the span over which the digital resolution of the instrument is applied. 
During a test you may not switch the gains of an analyzer's analog 
operational amplifier(s).
    (10) Zero and span all continuous analyzers using NIST-traceable 
gases that meet the specifications of Sec.  1065.750. Span FID analyzers 
on a carbon number basis of one (1), C1. For example, if you 
use a C3H8 span gas of concentration 200 
[micro]mol/mol, span the FID to respond with a value of 600 [micro]mol/
mol. Span FID analyzers consistent with the determination of their 
respective response factors, RF, and penetration fractions, PF, 
according to Sec.  1065.365.
    (11) We recommend that you verify gas analyzer responses after 
zeroing and spanning by sampling a calibration gas that has a 
concentration near one-half of the span gas concentration. Based on the 
results and good engineering judgment, you may decide whether or not to 
re-zero, re-span, or re-calibrate a gas analyzer before starting a test.
    (12) Drain any accumulated condensate from the intake air system 
before starting a duty cycle, as described in Sec.  1065.125(e)(1). If 
engine and aftertreatment preconditioning cycles are run before the duty 
cycle, treat the preconditioning cycles and any associated soak period 
as part of the duty cycle for the purpose of opening drains and draining 
condensate. Note that you must close any intake air condensate drains 
that are not representative of those normally open during in-use 
operation.
    (c) Start and run each test interval as described in this paragraph 
(c). The procedure varies depending on whether the test interval is part 
of a discrete-mode cycle, and whether the test interval includes engine 
starting. Note that the standard-setting part may apply different 
requirements for running test intervals. For example, 40 CFR part 1033 
specifies a different way to perform discrete-mode testing.
    (1) For steady-state discrete-mode duty cycles, start the duty cycle 
with the engine warmed-up and running as described in Sec.  
1065.501(c)(2)(i). Run each mode in the sequence specified in the 
standard-setting part. This will require controlling engine speed, 
engine load, or other operator demand settings as specified in the 
standard-setting part. Simultaneously start any electronic integrating 
devices, continuous data recording, and batch sampling. We recommend 
that you stabilize the engine for at least 5 minutes for each mode. Once 
sampling begins, sample continuously for at least 1 minute. Note that 
longer sample times may be needed for accurately measuring very low 
emission levels.
    (2) For transient and steady-state ramped-modal duty cycles that do 
not include engine starting, start the test interval with the engine 
running as soon as practical after completing engine preconditioning. 
Simultaneously start any electronic integrating devices, continuous data 
recording, batch sampling, and execution of the duty cycle.
    (3) If engine starting is part of the test interval, simultaneously 
start any electronic integrating devices, continuous data recording, and 
batch sampling before attempting to start the engine. Initiate the 
sequence of points in the duty cycle when the engine starts.
    (4) For batch sampling systems, you may advance or delay the start 
and end of sampling at the beginning and end of the test interval to 
improve the accuracy of the batch sample, consistent with good 
engineering judgment.
    (d) At the end of each test interval, continue to operate all 
sampling and dilution systems to allow the sampling system's response 
time to elapse. Then stop all sampling and recording, including the 
recording of background samples. Finally, stop any integrating devices 
and indicate the end of the duty cycle in the recorded data.
    (e) Shut down the engine if you have completed testing or if it is 
part of the duty cycle.
    (f) If testing involves another duty cycle after a soak period with 
the engine off, start a timer when the engine shuts down, and repeat the 
steps in paragraphs (b) through (e) of this section as needed.
    (g) Take the following steps after emission sampling is complete:
    (1) For any proportional batch sample, such as a bag sample or PM 
sample, verify that proportional sampling

[[Page 168]]

was maintained according to Sec.  1065.545. Void any samples that did 
not maintain proportional sampling according to Sec.  1065.545.
    (2) Place any used PM samples into covered or sealed containers and 
return them to the PM-stabilization environment. Follow the PM sample 
post-conditioning and total weighing procedures in Sec.  1065.595.
    (3) As soon as practical after the duty cycle is complete, or during 
the soak period if practical, perform the following:
    (i) Zero and span all batch gas analyzers no later than 30 minutes 
after the duty cycle is complete, or during the soak period if 
practical.
    (ii) Analyze any conventional gaseous batch samples no later than 30 
minutes after the duty cycle is complete, or during the soak period if 
practical.
    (iii) Analyze background samples no later than 60 minutes after the 
duty cycle is complete.
    (iv) Analyze non-conventional gaseous batch samples, such as ethanol 
(NMHCE) as soon as practical using good engineering judgment.
    (4) After quantifying exhaust gases, verify drift as follows:
    (i) For batch and continuous gas analyzers, record the mean analyzer 
value after stabilizing a zero gas to the analyzer. Stabilization may 
include time to purge the analyzer of any sample gas, plus any 
additional time to account for analyzer response.
    (ii) Record the mean analyzer value after stabilizing the span gas 
to the analyzer. Stabilization may include time to purge the analyzer of 
any sample gas, plus any additional time to account for analyzer 
response.
    (iii) Use these data to validate and correct for drift as described 
in Sec.  1065.550.
    (5) If you perform the optional carbon balance error verification, 
verify carbon balance error as specified in the standard-setting part 
and Sec.  1065.543. Calculate and report the three carbon balance error 
quantities for each test interval; carbon mass absolute error for a test 
interval, [epsi]aC, carbon mass rate absolute 
error for a test interval, [epsi]aCrate, and 
carbon mass relative error for a test interval, 
[epsi]rC. For duty cycles with multiple test 
intervals, you may calculate and report the composite carbon mass 
relative error, [epsi]rCcomp, for the whole duty 
cycle. If you report [epsi]rCcomp, you must still 
calculate and report [epsi]aC, 
[epsi]aCrate, and [epsi]rC 
for each test interval.
    (h) Unless the standard-setting part specifies otherwise, determine 
whether or not the test meets the cycle-validation criteria in Sec.  
1065.514.
    (1) If the criteria void the test, you may retest using the same 
denormalized duty cycle, or you may re-map the engine, denormalize the 
reference duty cycle based on the new map and retest the engine using 
the new denormalized duty cycle.
    (2) If the criteria void the test for a constant-speed engine only 
during commands of maximum test torque, you may do the following:
    (i) Determine the first and last feedback speeds at which maximum 
test torque was commanded.
    (ii) If the last speed is greater than or equal to 90% of the first 
speed, the test is void. You may retest using the same denormalized duty 
cycle, or you may re-map the engine, denormalize the reference duty 
cycle based on the new map and retest the engine using the new 
denormalized duty cycle.
    (iii) If the last speed is less than 90% of the first speed, reduce 
maximum test torque by 5%, and proceed as follows:
    (A) Denormalize the entire duty cycle based on the reduced maximum 
test torque according to Sec.  1065.512.
    (B) Retest the engine using the denormalized test cycle that is 
based on the reduced maximum test torque.
    (C) If your engine still fails the cycle criteria, reduce the 
maximum test torque by another 5% of the original maximum test torque.
    (D) If your engine fails after repeating this procedure four times, 
such that your engine still fails after you have reduced the maximum 
test torque by 20% of the original maximum test torque, notify us and we 
will consider specifying a more appropriate duty cycle for your engine 
under the provisions of Sec.  1065.10(c).
    (i) [Reserved]
    (j) Measure and record ambient temperature, pressure, and humidity, 
as appropriate. For testing the following

[[Page 169]]

engines, you must record ambient temperature continuously to verify that 
it remains within the pre-test temperature range as specified in Sec.  
1065.520(b):
    (1) Air-cooled engines.
    (2) Engines equipped with auxiliary emission control devices that 
sense and respond to ambient temperature.
    (3) Any other engine for which good engineering judgment indicates 
this is necessary to remain consistent with Sec.  1065.10(c)(1).

[73 FR 37321, June 30, 2008, as amended at 75 FR 23043, Apr. 30, 2010; 
76 FR 57451, Sept. 15, 2011; 79 FR 23776, Apr. 28, 2014; 86 FR 34546, 
June 29, 2021; 87 FR 64865, Oct. 26, 2022; 88 FR 4679, Jan. 24, 2023]



Sec.  1065.543  Carbon balance error verification.

    (a) This optional carbon balance error verification compares 
independently calculated quantities of carbon flowing into and out of an 
engine system. The engine system includes aftertreatment devices as 
applicable. Calculating carbon intake considers carbon-carrying streams 
flowing into the system, including intake air, fuel, and optionally DEF 
or other fluids. Carbon flow out of the system comes from exhaust 
emission calculations. Note that this verification is not valid if you 
calculate exhaust molar flow rate using fuel rate and chemical balance 
as described in Sec.  1065.655(f)(3) because carbon flows into and out 
of the system are not independent. Use good engineering judgment to 
ensure that carbon mass in and carbon mass out data signals align.
    (b) Perform the carbon balance error verification after emission 
sampling is complete for a test sequence as described in Sec.  
1065.530(g)(5). Testing must include measured values as needed to 
determine intake air, fuel flow, and carbon-related gaseous exhaust 
emissions. You may optionally account for the flow of carbon-carrying 
fluids other than intake air and fuel into the system. Perform carbon 
balance error verification as follows:
    (1) Calculate carbon balance error quantities as described in Sec.  
1065.643. The three quantities for individual test intervals are carbon 
mass absolute error, [epsi]aC, carbon mass rate 
absolute error, [epsi]aCrate, and carbon mass 
relative error, [epsi]rC. Determine 
[epsi]aC, [epsi]aCrate, and 
[epsi]rC for all test intervals. You may determine 
composite carbon mass relative error, 
[epsi]rCcomp, as a fourth quantity that optionally 
applies for duty cycles with multiple test intervals.
    (2) You meet the carbon balance error verification for a test 
sequence if all test intervals pass the test-interval criteria. A test 
interval passes if at least one of the absolute values of the three 
carbon balance error quantities for test intervals, 
[epsi]aC, [epsi]aCrate, and 
[epsi]rC, is at or below its respective limit 
value in paragraphs (b)(2)(i) through (iii) of this section. You meet 
the carbon balance error verification for a duty cycle with multiple 
test intervals if the duty cycle passes the duty-cycle criterion. A duty 
cycle passes if the absolute value of the composite carbon mass relative 
error quantity, [epsi]rCcomp, is at or below the 
limit value in paragraph (b)(2)(iii) of this section. Unless specified 
otherwise in the standard-setting part, if verification fails for a test 
sequence, you may repeat the entire test sequence or repeat individual 
test intervals as described in Sec.  1065.526.
    (i) Calculate the carbon mass absolute error limit, 
L[egr]aC, in grams to three decimal places for comparison to 
the absolute value of [epsi]aC, using the following equation:
[GRAPHIC] [TIFF OMITTED] TR24JA23.104

Where:

c = power-specific carbon mass absolute error coefficient = 0.007 g/kW.
Pmax = maximum power from the engine map generated according 
          to Sec.  1065.510. If measured Pmax is not 
          available, use a manufacturer-declared value for 
          Pmax.

                                Example:

c = 0.007 g/kW
Pmax = 230.0 kW
L[egr]aC = 0.007 [middot] 230.0
L[egr]aC = 1.610 g

    (ii) Calculate the carbon mass rate absolute error limit, 
L[egr]aCrate, in grams per hour to three decimal places for comparison 
to the absolute value of [epsi]aCrate, using the 
following equation:
[GRAPHIC] [TIFF OMITTED] TR24JA23.105


[[Page 170]]


Where:

d = power-specific carbon mass rate absolute error coefficient = 0.31 g/
          (kW[middot]hr).
Pmax = maximum power from the engine map generated according 
          to Sec.  1065.510. If measured Pmax is not 
          available, use a manufacturer-declared value for 
          Pmax.

                                Example:

d = 0.31 g/(kW[middot]hr)
Pmax = 230.0 kW
L[egr]aCrate = 0.31.230.0
L[egr]aCrate = 71.300 g/hr

    (iii) The carbon mass relative error limit, L[epsi]rC, is 
0.020 for comparison to the absolute value of 
[epsi]rC, and to the absolute value of 
[epsi]rCcomp.
    (c) A failed carbon balance error verification might indicate one or 
more problems requiring corrective action, as follows:

  Table 1 of Sec.   1065.543--Troubleshooting Guide for Carbon Balance
                           Error Verification
------------------------------------------------------------------------
                                                        Recommended
        Area of concern              Problem         corrective action
------------------------------------------------------------------------
Gas analyzer system...........  Incorrect          Calibrate NDIR and
                                 analyzer           THC analyzers.
                                 calibration.
                                Incorrect time     Determine
                                 alignment          transformation time,
                                 between flow and   t50, for continuous
                                 concentration      gas analyzers and
                                 data.              time-align flow and
                                                    concentration data
                                                    as described in Sec.
                                                      1065.650(c)(2)(i).
                                Problems with the  Inspect sample system
                                 sample system.     components such as
                                                    sample lines,
                                                    filters, chillers,
                                                    and pumps for leaks,
                                                    operating
                                                    temperature, and
                                                    contamination.
Fuel flow measurement.........  Zero shift of      Perform an in-situ
                                 fuel flow rate     zero adjustment.
                                 meter.
                                Change in fuel     Calibrate the fuel
                                 flow meter         flow meter as
                                 calibration.       described in Sec.
                                                    1065.320.
                                Incorrect time     Verify alignment of
                                 alignment of       carbon mass in and
                                 fuel flow data.    carbon mass out data
                                                    streams.
                                Short sampling     For test intervals
                                 periods.           with varying
                                                    duration, such as
                                                    discrete-mode steady-
                                                    state duty cycles,
                                                    make the test
                                                    intervals longer to
                                                    improve accuracy
                                                    when measuring low
                                                    fuel flow rates.
                                Fluctuations in    Improve stability of
                                 the fuel           the fuel temperature
                                 conditioning       and pressure
                                 system.            conditioning system
                                                    to improve accuracy
                                                    when measuring low
                                                    fuel flow rates.
Dilute testing using a CVS      Leaks............  Inspect exhaust
 system.                                            system and CVS
                                                    tunnel, connections,
                                                    and fasteners.
                                                    Repair or replace
                                                    components as
                                                    needed. A leak in
                                                    the exhaust transfer
                                                    tube to the CVS may
                                                    result in negative
                                                    values for carbon
                                                    balance error.
                                Poor mixing......  Perform the
                                                    verification related
                                                    to mixing in Sec.
                                                    1065.341(f).
                                Change in CVS      Calibrate the CVS
                                 calibration.       flow meter as
                                                    described in Sec.
                                                    1065.340.
                                Flow meter         Inspect the CVS
                                 entrance effects.  tunnel to determine
                                                    whether entrance
                                                    effects from the
                                                    piping configuration
                                                    upstream of the flow
                                                    meter adversely
                                                    affect flow
                                                    measurement.
                                Other problems     Inspect hardware and
                                 with the CVS or    software for the CVS
                                 sampling           system and CVS
                                 verification       verification system
                                 hardware or        for discrepancies.
                                 software.
Raw testing using intake air    Leaks............  Inspect intake air
 flow measurement or direct                         and exhaust systems,
 exhaust flow measurement.                          connections,
                                                    fasteners. Repair or
                                                    replace components
                                                    as needed.
                                Zero shift of      Perform an in-situ
                                 intake air flow    zero adjustment.
                                 rate meter.
                                Change in intake   Calibrate the intake
                                 air flow meter     air flow meter as
                                 calibration.       described in Sec.
                                                    1065.325.
                                Zero shift of      Perform an in-situ
                                 exhaust flow       zero adjustment.
                                 rate meter.
                                Change in exhaust  Calibrate the exhaust
                                 flow meter         flow meter as
                                 calibration.       described in Sec.
                                                    1065.330.
                                Flow meter         Inspect intake air
                                 entrance effects.  and exhaust systems
                                                    to determine whether
                                                    entrance effects
                                                    from the piping
                                                    configuration
                                                    upstream and
                                                    downstream of the
                                                    intake air flow
                                                    meter or the exhaust
                                                    flow meter adversely
                                                    affect flow
                                                    measurement.
                                Other problems     Look for
                                 with the intake    discrepancies in the
                                 air flow and       hardware and
                                 exhaust flow       software for
                                 measurement        measuring intake air
                                 hardware or        flow and exhaust
                                 software.          flow.
                                Poor mixing......  Ensure that all
                                                    streams are well
                                                    mixed.
Accuracy of fluid properties..  Inaccurate fluid   If defaults are used,
                                 properties.        use measured values.
                                                    If measured values
                                                    are used, verify
                                                    fluid property
                                                    determination.
------------------------------------------------------------------------


[[Page 171]]


[86 FR 34547, June 29, 2021; 87 FR 64865, Oct. 26, 2022; 88 FR 4679, 
Jan. 24, 2023]



Sec.  1065.545  Verification of proportional flow control for batch sampling.

    For any proportional batch sample such as a bag or PM filter, 
demonstrate that proportional sampling was maintained using one of the 
following, noting that you may omit up to 5% of the total number of data 
points as outliers:
    (a) For any pair of sample and total flow rates, use continuous 
recorded data or 1 Hz means. Total flow rate means the raw exhaust flow 
rate for raw exhaust sampling and the dilute exhaust flow rate for CVS 
sampling. For each test interval, determine the standard error of the 
estimate, SEE, of the sample flow rate versus the total flow rate as 
described in Sec.  1065.602, forcing the intercept to zero. Determine 
the mean sample flow rate over each test interval as described in Sec.  
1065.602. For each test interval, demonstrate that SEE is at or below 
3.5% of the mean sample flow rate.
    (b) For any pair of sample and total flow rates, use continuous 
recorded data or 1 Hz means. Total flow rate means the raw exhaust flow 
rate for raw exhaust sampling and the dilute exhaust flow rate for CVS 
sampling. For each test interval, demonstrate that each flow rate is 
constant within 2.5% of its respective mean or 
target flow rate. You may use the following options instead of recording 
the respective flow rate of each type of meter:
    (1) Critical-flow venturi option. For critical-flow venturis, you 
may use recorded venturi-inlet conditions or their 1 Hz means. 
Demonstrate that the flow density at the venturi inlet was constant 
within 2.5% of the mean or target density over 
each test interval. For a CVS critical-flow venturi, you may demonstrate 
this by showing that the absolute temperature at the venturi inlet was 
constant within 4% of the mean or target absolute 
temperature over each test interval.
    (2) Positive-displacement pump option. You may use recorded pump-
inlet conditions or their 1 Hz means. Demonstrate that the flow density 
at the pump inlet was constant within 2.5% of the 
mean or target density over each test interval. For a CVS pump, you may 
demonstrate this by showing that the absolute temperature at the pump 
inlet was constant within 2% of the mean or target 
absolute temperature over each test interval.
    (c) Using good engineering judgment, demonstrate with an engineering 
analysis that the proportional-flow control system inherently ensures 
proportional sampling under all circumstances expected during testing. 
For example, you might use CFVs for both sample flow and total dilute 
exhaust (CVS) flow and demonstrate that they always have the same inlet 
pressures and temperatures and that they always operate under critical-
flow conditions.

[79 FR 23777, Apr. 28, 2014, as amended at 86 FR 34548, June 29, 2021; 
88 FR 4679, Jan. 24, 2023]



Sec.  1065.546  Verification of minimum dilution ratio for PM batch sampling.

    Use continuous flows and/or tracer gas concentrations for transient 
and ramped-modal cycles to verify the minimum dilution ratios for PM 
batch sampling as specified in Sec.  1065.140(e)(2) over the test 
interval. You may use mode-average values instead of continuous 
measurements for discrete mode steady-state duty cycles. Determine the 
minimum primary and minimum overall dilution ratios using one of the 
following methods (you may use a different method for each stage of 
dilution):
    (a) Determine minimum dilution ratio based on molar flow data. This 
involves determination of at least two of the following three 
quantities: raw exhaust flow (or previously diluted flow), dilution air 
flow, and dilute exhaust flow. You may determine the raw exhaust flow 
rate based on the measured intake air or fuel flow rate and the raw 
exhaust chemical balance terms as given in Sec.  1065.655(f). You may 
determine the raw exhaust flow rate based on the measured intake air and 
dilute exhaust molar flow rates and the dilute exhaust chemical balance 
terms as given in Sec.  1065.655(g). You may alternatively estimate the 
molar raw exhaust flow rate based on intake air, fuel rate measurements, 
and fuel properties, consistent with good engineering judgment.

[[Page 172]]

    (b) Determine minimum dilution ratio based on tracer gas (e.g., 
CO2) concentrations in the raw (or previously diluted) and 
dilute exhaust corrected for any removed water.
    (c) Use good engineering judgment to develop your own method of 
determining dilution ratios.

[75 FR 23043, Apr. 30, 2010, as amended at 76 FR 57451, Sept. 15, 2011; 
79 FR 23778, Apr. 28, 2014; 81 FR 74169, Oct. 25, 2016]



Sec.  1065.550  Gas analyzer range verification and drift verification.

    (a) Range verification. If an analyzer operated above 100% of its 
range at any time during the test, perform the following steps:
    (1) For batch sampling, re-analyze the sample using the lowest 
analyzer range that results in a maximum instrument response below 100%. 
Report the result from the lowest range from which the analyzer operates 
below 100% of its range.
    (2) For continuous sampling, repeat the entire test using the next 
higher analyzer range. If the analyzer again operates above 100% of its 
range, repeat the test using the next higher range. Continue to repeat 
the test until the analyzer always operates at less than 100% of its 
range.
    (b) Drift verification. Gas analyzer drift verification is required 
for all gaseous exhaust constituents for which an emission standard 
applies. It is also required for CO2 even if there is no 
CO2 emission standard. It is not required for other gaseous 
exhaust constituents for which only a reporting requirement applies 
(such as CH4 and N2O).
    (1) Verify drift using one of the following methods:
    (i) For regulated exhaust constituents determined from the mass of a 
single component, perform drift verification based on the regulated 
constituent. For example, when NOX mass is determined with a 
dry sample measured with a CLD and the removed water is corrected based 
on measured CO2, CO, THC, and NOX concentrations, 
you must verify the calculated NOX value.
    (ii) For regulated exhaust constituents determined from the masses 
of multiple subcomponents, perform the drift verification based on 
either the regulated constituent or all the mass subcomponents. For 
example, when NOX is measured with separate NO and 
NO2 analyzers, you must verify either the NOX 
value or both the NO and NO2 values.
    (iii) For regulated exhaust constituents determined from the 
concentrations of multiple gaseous emission subcomponents prior to 
performing mass calculations, perform drift verification on the 
regulated constituent. You may not verify the concentration 
subcomponents (e.g., THC and CH4 for NMHC) separately. For 
example, for NMHC measurements, perform drift verification on NMHC; do 
not verify THC and CH4 separately.
    (2) Drift verification requires two sets of emission calculations. 
For each set of calculations, include all the constituents in the drift 
verification. Calculate one set using the data before drift correction 
and calculate the other set after correcting all the data for drift 
according to Sec.  1065.672. Note that for purposes of drift 
verification, you must leave unaltered any negative emission results 
over a given test interval (i.e., do not set them to zero). These 
unaltered results are used when verifying either test interval results 
or composite brake-specific emissions over the entire duty cycle for 
drift. For each constituent to be verified, both sets of calculations 
must include the following:
    (i) Calculated mass (or mass rate) emission values over each test 
interval.
    (ii) If you are verifying each test interval based on brake-specific 
values, calculate brake-specific emission values over each test 
interval.
    (iii) If you are verifying over the entire duty cycle, calculate 
composite brake-specific emission values.
    (3) The duty cycle is verified for drift if you satisfy the 
following criteria:
    (i) For each regulated gaseous exhaust constituent, you must satisfy 
one of the following:
    (A) For each test interval of the duty cycle, the difference between 
the uncorrected and the corrected brake-specific emission values of the 
regulated constituent must be within 4% of the 
uncorrected value or the applicable

[[Page 173]]

emissions standard, whichever is greater. Alternatively, the difference 
between the uncorrected and the corrected emission mass (or mass rate) 
values of the regulated constituent must be within 4% of the uncorrected value or the composite work (or 
power) multiplied by the applicable emissions standard, whichever is 
greater. For purposes of verifying each test interval, you may use 
either the reference or actual composite work (or power).
    (B) For each test interval of the duty cycle and for each mass 
subcomponent of the regulated constituent, the difference between the 
uncorrected and the corrected brake-specific emission values must be 
within 4% of the uncorrected value. Alternatively, 
the difference between the uncorrected and the corrected emissions mass 
(or mass rate) values must be within 4% of the 
uncorrected value.
    (C) For the entire duty cycle, the difference between the 
uncorrected and the corrected composite brake-specific emission values 
of the regulated constituent must be within 4% of 
the uncorrected value or applicable emission standard, whichever is 
greater.
    (D) For the entire duty cycle and for each subcomponent of the 
regulated constituent, the difference between the uncorrected and the 
corrected composite brake-specific emission values must be within 4% of the uncorrected value.
    (ii) Where no emission standard applies for CO2, you must 
satisfy one of the following:
    (A) For each test interval of the duty cycle, the difference between 
the uncorrected and the corrected brake-specific CO2 values 
must be within 4% of the uncorrected value; or the 
difference between the uncorrected and the corrected CO2 mass 
(or mass rate) values must be within 4% of the 
uncorrected value.
    (B) For the entire duty cycle, the difference between the 
uncorrected and the corrected composite brake-specific CO2 
values must be within 4% of the uncorrected value.
    (4) If the test is not verified for drift as described in paragraph 
(b)(1) of this section, you may consider the test results for the duty 
cycle to be valid only if, using good engineering judgment, the observed 
drift does not affect your ability to demonstrate compliance with the 
applicable emission standards. For example, if the drift-corrected value 
is less than the standard by at least two times the absolute difference 
between the uncorrected and corrected values, you may consider the data 
to be verified for demonstrating compliance with the applicable 
standard.

[79 FR 23778, Apr. 28, 2014]



Sec.  1065.590  PM sampling media (e.g., filters) preconditioning and tare weighing.

    Before an emission test, take the following steps to prepare PM 
sampling media (e.g., filters) and equipment for PM measurements:
    (a) Make sure the balance and PM-stabilization environments meet the 
periodic verifications in Sec.  1065.390.
    (b) Visually inspect unused sample media (e.g., filters) for defects 
and discard defective media.
    (c) To handle PM sampling media (e.g., filters), use electrically 
grounded tweezers or a grounding strap, as described in Sec.  1065.190.
    (d) Place unused sample media (e.g., filters) in one or more 
containers that are open to the PM-stabilization environment. If you are 
using filters, you may place them in the bottom half of a filter 
cassette.
    (e) Stabilize sample media (e.g., filters) in the PM-stabilization 
environment. Consider an unused sample medium stabilized as long as it 
has been in the PM-stabilization environment for a minimum of 30 min, 
during which the PM-stabilization environment has been within the 
specifications of Sec.  1065.190.
    (f) Weigh the sample media (e.g., filters) automatically or 
manually, as follows:
    (1) For automatic weighing, follow the automation system 
manufacturer's instructions to prepare samples for weighing. This may 
include placing the samples in a special container.
    (2) Use good engineering judgment to determine if substitution 
weighing is necessary to show that an engine meets the applicable 
standard. You may follow the substitution weighing

[[Page 174]]

procedure in paragraph (j) of this section, or you may develop your own 
procedure.
    (g) Correct the measured mass of each sample medium (e.g., filter) 
for buoyancy as described in Sec.  1065.690. These buoyancy-corrected 
values are subsequently subtracted from the post-test mass of the 
corresponding sample media (e.g., filters) and collected PM to determine 
the mass of PM emitted during the test.
    (h) You may repeat measurements to determine the mean mass of each 
sample medium (e.g., filter). Use good engineering judgment to exclude 
outliers from the calculation of mean mass values.
    (i) If you use filters as sample media, load unused filters that 
have been tare-weighed into clean filter cassettes and place the loaded 
cassettes in a clean, covered or sealed container before removing them 
from the stabilization environment for transport to the test site for 
sampling. We recommend that you keep filter cassettes clean by 
periodically washing or wiping them with a compatible solvent applied 
using a lint-free cloth. Depending upon your cassette material, ethanol 
(C2H5OH) might be an acceptable solvent. Your 
cleaning frequency will depend on your engine's level of PM and HC 
emissions.
    (j) Substitution weighing involves measurement of a reference weight 
before and after each weighing of the PM sampling medium (e.g., the 
filter). While substitution weighing requires more measurements, it 
corrects for a balance's zero-drift and it relies on balance linearity 
only over a small range. This is most advantageous when quantifying net 
PM masses that are less than 0.1% of the sample medium's mass. However, 
it may not be advantageous when net PM masses exceed 1% of the sample 
medium's mass. If you utilize substitution weighing, it must be used for 
both pre-test and post-test weighing. The same substitution weight must 
be used for both pre-test and post-test weighing. Correct the mass of 
the substitution weight for buoyancy if the density of the substitution 
weight is less than 2.0 g/cm\3\. The following steps are an example of 
substitution weighing:
    (1) Use electrically grounded tweezers or a grounding strap, as 
described in Sec.  1065.190.
    (2) Use a static neutralizer as described in Sec.  1065.190 to 
minimize static electric charge on any object before it is placed on the 
balance pan.
    (3) Select and weigh a substitution weight that meets the 
requirements for calibration weights found in Sec.  1065.790. The 
substitution weight must also have the same density as the weight you 
use to span the microbalance, and be similar in mass to an unused sample 
medium (e.g., filter). A 47 mm PTFE membrane filter will typically have 
a mass in the range of 80 to 100 mg.
    (4) Record the stable balance reading, then remove the substitution 
weight.
    (5) Weigh an unused sample medium (e.g., a new filter), record the 
stable balance reading and record the balance environment's dewpoint, 
ambient temperature, and atmospheric pressure.
    (6) Reweigh the substitution weight and record the stable balance 
reading.
    (7) Calculate the arithmetic mean of the two substitution-weight 
readings that you recorded immediately before and after weighing the 
unused sample. Subtract that mean value from the unused sample reading, 
then add the true mass of the substitution weight as stated on the 
substitution-weight certificate. Record this result. This is the unused 
sample's tare weight without correcting for buoyancy.
    (8) Repeat these substitution-weighing steps for the remainder of 
your unused sample media.
    (9) Once weighing is completed, follow the instructions given in 
paragraphs (g) through (i) of this section.

[73 FR 37323, June 30, 2008, as amended at 81 FR 74169, Oct. 25, 2016]



Sec.  1065.595  PM sample post-conditioning and total weighing.

    After testing is complete, return the sample media (e.g., filters) 
to the weighing and PM-stabilization environments.
    (a) Make sure the weighing and PM-stabilization environments meet 
the ambient condition specifications in Sec.  1065.190(e)(1). If those 
specifications are not met, leave the test sample media (e.g., filters) 
covered until proper conditions have been met.

[[Page 175]]

    (b) In the PM-stabilization environment, remove PM samples from 
sealed containers. If you use filters, you may remove them from their 
cassettes before or after stabilization. We recommend always removing 
the top portion of the cassette before stabilization. When you remove a 
filter from a cassette, separate the top half of the cassette from the 
bottom half using a cassette separator designed for this purpose.
    (c) To handle PM samples, use electrically grounded tweezers or a 
grounding strap, as described in Sec.  1065.190.
    (d) Visually inspect the sampling media (e.g., filters) and 
collected particulate. If either the sample media (e.g., filters) or 
particulate sample appear to have been compromised, or the particulate 
matter contacts any surface other than the filter, the sample may not be 
used to determine particulate emissions. In the case of contact with 
another surface, clean the affected surface before continuing.
    (e) To stabilize PM samples, place them in one or more containers 
that are open to the PM-stabilization environment, as described in Sec.  
1065.190. If you expect that a sample medium's (e.g., filter's) total 
surface concentration of PM will be less than 400 [micro]g, assuming a 
38 mm diameter filter stain area, expose the filter to a PM-
stabilization environment meeting the specifications of Sec.  1065.190 
for at least 30 minutes before weighing. If you expect a higher PM 
concentration or do not know what PM concentration to expect, expose the 
filter to the stabilization environment for at least 60 minutes before 
weighing. Note that 400 [micro]g on sample media (e.g., filters) is an 
approximate net mass of 0.07 g/kW [middot] hr for a hot-start test with 
compression-ignition engines tested according to 40 CFR part 86, subpart 
N, or 50 mg/mile for light-duty vehicles tested according to 40 CFR part 
86, subpart B.
    (f) Repeat the procedures in Sec.  1065.590(f) through (i) to 
determine post-test mass of the sample media (e.g., filters).
    (g) Subtract each buoyancy-corrected tare mass of the sample medium 
(e.g., filter) from its respective buoyancy-corrected mass. The result 
is the net PM mass, mPM. Use mPM in emission 
calculations in Sec.  1065.650.

[73 FR 37323, June 30, 2008]



              Subpart G_Calculations and Data Requirements



Sec.  1065.601  Overview.

    (a) This subpart describes how to--
    (1) Use the signals recorded before, during, and after an emission 
test to calculate brake-specific emissions of each measured exhaust 
constituent.
    (2) Perform calculations for calibrations and performance checks.
    (3) Determine statistical values.
    (b) You may use data from multiple systems to calculate test results 
for a single emission test, consistent with good engineering judgment. 
You may also make multiple measurements from a single batch sample, such 
as multiple weighings of a PM filter or multiple readings from a bag 
sample. Although you may use an average of multiple measurements from a 
single test, you may not use test results from multiple emission tests 
to report emissions.
    (1) We allow weighted means where appropriate.
    (2) You may discard statistical outliers, but you must report all 
results.
    (3) For emission measurements related to durability testing, we may 
allow you to exclude certain test points other than statistical outliers 
relative to compliance with emission standards, consistent with good 
engineering judgment and normal measurement variability; however, you 
must include these results when calculating the deterioration factor. 
This would allow you to use durability data from an engine that has an 
intermediate test result above the standard that cannot be discarded as 
a statistical outlier, as long as good engineering judgment indicates 
that the test result does not represent the engine's actual emission 
level. Note that good engineering judgment would preclude you from 
excluding endpoints. Also, if normal measurement variability causes 
emission results below zero, include the negative result in calculating 
the deterioration factor to avoid an upward

[[Page 176]]

bias. These provisions related to durability testing are intended to 
address very stringent standards where measurement variability is large 
relative to the emission standard.
    (c) You may use any of the following calculations instead of the 
calculations specified in this subpart G:
    (1) Mass-based emission calculations prescribed by the International 
Organization for Standardization (ISO), according to ISO 8178, except 
the following:
    (i) ISO 8178-1 Section 14.4, NOX Correction for Humidity 
and Temperature. See Sec.  1065.670 for approved methods for humidity 
corrections.
    (ii) ISO 8178-1 Section 15.1, Particulate Correction Factor for 
Humidity.
    (2) Other calculations that you show are equivalent to within 0.1% of the brake-specific emission results determined 
using the calculations specified in this subpart G.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37324, June 30, 2008; 
74 FR 56516, Oct. 30, 2009; 75 FR 23044, Apr. 30, 2010; 79 FR 23778, 
Apr. 28, 2014]



Sec.  1065.602  Statistics.

    (a) Overview. This section contains equations and example 
calculations for statistics that are specified in this part. In this 
section we use the letter ``y'' to denote a generic measured quantity, 
the superscript over-bar ``-'' to denote an arithmetic mean, 
and the subscript ``ref'' to denote the reference quantity 
being measured.
    (b) Arithmetic mean. Calculate an arithmetic mean, y, as follows:
    [GRAPHIC] [TIFF OMITTED] TR29JN21.176
    
                                Example:

N = 3
y1 = 10.60
y2 = 11.91
yN = y3 = 11.09
[GRAPHIC] [TIFF OMITTED] TR29JN21.177

y = 11.20

    (c) Standard deviation. Calculate the standard deviation for a non-
biased (e.g., N-1) sample, [sigma], as follows:
[GRAPHIC] [TIFF OMITTED] TR29JN21.178


[[Page 177]]



                                Example:

N = 3
y1 = 10.60
y2 = 11.91
yN = y3 = 11.09
y = 11.20
[GRAPHIC] [TIFF OMITTED] TR29JN21.179

[sigma]y = 0.6619

    (d) Root mean square. Calculate a root mean square, rmsy, 
as follows:
[GRAPHIC] [TIFF OMITTED] TR29JN21.180

                                Example:

N = 3
y1 = 10.60
y2 = 11.91
yN = y3 = 11.09
[GRAPHIC] [TIFF OMITTED] TR29JN21.181

rmsy = 11.21

    (e) Accuracy. Determine accuracy as described in this paragraph (e). 
Make multiple measurements of a standard quantity to create a set of 
observed values, yi, and compare each observed value to the known value 
of the standard quantity. The standard quantity may have a single known 
value, such as a gas standard, or a set of known values of negligible 
range, such as a known applied pressure produced by a calibration device 
during repeated applications. The known value of the standard quantity 
is represented by yrefi. If you use a standard quantity with 
a single value, yrefi would be constant. Calculate an 
accuracy value as follows:

    [GRAPHIC] [TIFF OMITTED] TR29JN21.182
    
                                Example:

yref = 1800.0
N = 3
y1 = 1806.4
y2 = 1803.1
y3 = 1798.9

[[Page 178]]

[GRAPHIC] [TIFF OMITTED] TR29JN21.183

accuracy = 2.8

    (f) t-test. Determine if your data passes a t-test by using the 
following equations and tables: (1) For an unpaired t-test, calculate 
the t statistic and its number of degrees of freedom, v, as follows:
[GRAPHIC] [TIFF OMITTED] TR29JN21.184

[GRAPHIC] [TIFF OMITTED] TR29JN21.185

                                Example:

Yref = 1205.3
Y = 1123.8
[sigma]ref = 9.399
[sigma]y = 10.583
Nref = 11
N = 7
[GRAPHIC] [TIFF OMITTED] TR29JN21.186

t = 16.63
[sigma]ref = 9.399
[sigma]y = 10.583
Nref = 11
N = 7

[[Page 179]]

[GRAPHIC] [TIFF OMITTED] TR29JN21.187

v = 11.76

    (2) For a paired t-test, calculate the t statistic and its number of 
degrees of freedom, v, as follows, noting that the [epsi]i are the 
errors (e.g., differences) between each pair of yrefi and yi:
[GRAPHIC] [TIFF OMITTED] TR29JN21.188

                               Example 1:

[egr] = -0.12580
N = 16
[sigma][egr] = 0.04837
[GRAPHIC] [TIFF OMITTED] TR29JN21.189

t = 10.403
v = N-1

                               Example 2:

N = 16
v = 16-1
v = 15

    (3) Use Table 1 of this section to compare t to the tcrit 
values tabulated versus the number of degrees of freedom. If t is less 
than tcrit, then t passes the t-test. The Microsoft Excel 
software has a TINV function that returns results equivalent results and 
may be used in place of Table 1, which follows:

 Table 1 of Sec.   1065.602--Critical t Values Versus Number of Degrees
                            of Freedom, v \a\
------------------------------------------------------------------------
                                                    Confidence
                    v                    -------------------------------
                                                90%             95%
------------------------------------------------------------------------
1.......................................           6.314          12.706
2.......................................           2.920           4.303
3.......................................           2.353           3.182
4.......................................           2.132           2.776
5.......................................           2.015           2.571
6.......................................           1.943           2.447
7.......................................           1.895           2.365
8.......................................           1.860           2.306
9.......................................           1.833           2.262
10......................................           1.812           2.228
11......................................           1.796           2.201
12......................................           1.782           2.179
13......................................           1.771           2.160
14......................................           1.761           2.145
15......................................           1.753           2.131
16......................................           1.746           2.120
18......................................           1.734           2.101
20......................................           1.725           2.086
22......................................           1.717           2.074
24......................................           1.711           2.064
26......................................           1.706           2.056
28......................................           1.701           2.048
30......................................           1.697           2.042

[[Page 180]]

 
35......................................           1.690           2.030
40......................................           1.684           2.021
50......................................           1.676           2.009
70......................................           1.667           1.994
100.....................................           1.660           1.984
1000+...................................           1.645           1.960
------------------------------------------------------------------------
a Use linear interpolation to establish values not shown here.

    (g) F-test. Calculate the F statistic as follows:
    [GRAPHIC] [TIFF OMITTED] TR29JN21.190
    
                                Example:
[GRAPHIC] [TIFF OMITTED] TR29JN21.191

F = 1.268

    (1) For a 90% confidence F-test, use the following table to compare 
F to the Fcrit90 values tabulated versus (N-1) and 
(Nref-1). If F is less than Fcrit90, then F passes 
the F-test at 90% confidence.

[[Page 181]]

[GRAPHIC] [TIFF OMITTED] TR29JN21.192

    (2) For a 95% confidence F-test, use the following table to compare 
F to the Fcrit90 values tabulated versus (N-1) and 
(Nref-1). If F is less than Fcrit95, then F passes 
the F-test at 95% confidence.

[[Page 182]]

[GRAPHIC] [TIFF OMITTED] TR29JN21.193

    (h) Slope. Calculate a least-squares regression slope, 
a1y, using one of the following two methods:
    (1) If the intercept floats, i.e., is not forced through zero:

[[Page 183]]

[GRAPHIC] [TIFF OMITTED] TR29JN21.194

                                Example:

N = 6000
y1 = 2045.8
y = 1050.1
yref1 = 2045.0
yref = 1055.3
[GRAPHIC] [TIFF OMITTED] TR29JN21.195

a1y = 1.0110

    (2) If the intercept is forced through zero, such as for verifying 
proportional sampling:
[GRAPHIC] [TIFF OMITTED] TR29JN21.196

                                Example:

N = 6000
y1 = 2045.8
yref1 = 2045.0
[GRAPHIC] [TIFF OMITTED] TR29JN21.197

a1y = 1.0110

    (i) Intercept. For a floating intercept, calculate a least-squares 
regression intercept, a0y, as follows:

[[Page 184]]

[GRAPHIC] [TIFF OMITTED] TR29JN21.198

                                Example:

y = 1050.1
a1y = 1.0110
yref = 1055.3
a0y = 1050.1 - (1.0110 [middot] 1055.3)
a0y = -16.8083

    (j) Standard error of the estimate. Calculate a standard error of 
the estimate, SEE, using one of the following two methods:
    (1) For a floating intercept:
    [GRAPHIC] [TIFF OMITTED] TR29JN21.199
    
                                Example:

N = 6000
y1 = 2045.8
a0y = -16.8083
a1y = 1.0110
yref1 = 2045.0
[GRAPHIC] [TIFF OMITTED] TR29JN21.200

SEEy = 5.348

    (2) If the intercept is forced through zero, such as for verifying 
proportional sampling:
[GRAPHIC] [TIFF OMITTED] TR29JN21.201

                                Example:

N = 6000
y1 = 2045.8
a1y = 1.0110
yref1 = 2045.0

[[Page 185]]

[GRAPHIC] [TIFF OMITTED] TR29JN21.202

SEEy = 5.347

    (k) Coefficient of determination. Calculate a coefficient of 
determination, ry\2\, as follows:
[GRAPHIC] [TIFF OMITTED] TR29JN21.203

                                Example:

N = 6000
y1 = 2045.8
a0y = -16.8083
a1y = 1.0110
yref1 = 2045.0
y = 1480.5
[GRAPHIC] [TIFF OMITTED] TR29JN21.204

    (l) Flow-weighted mean concentration. In some sections of this part, 
you may need to calculate a flow-weighted mean concentration to 
determine the applicability of certain provisions. A flow-weighted mean 
is the mean of a quantity after it is weighted proportional to a 
corresponding flow rate. For example, if a gas concentration is measured 
continuously from the raw exhaust of an engine, its flow-weighted mean 
concentration is the sum of the products of each recorded concentration 
times its respective exhaust molar flow rate, divided by the sum of the 
recorded flow rate values. As another example, the bag concentration 
from a CVS system is the same as the flow-weighted mean concentration 
because the CVS system itself flow-weights the bag concentration. You 
might already expect a certain flow-weighted mean concentration of an 
emission at its standard based on previous testing with similar engines 
or testing with similar equipment and instruments. If you need to 
estimate your expected flow-weighted mean concentration of an emission 
at its standard, we recommend using the following examples as a guide 
for how to estimate the flow-weighted mean concentration expected at the 
standard. Note that these examples are not exact and that they contain 
assumptions that are not always valid. Use good engineering judgment to 
determine if you can use similar assumptions.
    (1) To estimate the flow-weighted mean raw exhaust NOX 
concentration

[[Page 186]]

from a turbocharged heavy-duty compression-ignition engine at a 
NOX standard of 2.5 g/(kW[middot]hr), you may do the 
following:
    (i) Based on your engine design, approximate a map of maximum torque 
versus speed and use it with the applicable normalized duty cycle in the 
standard-setting part to generate a reference duty cycle as described in 
Sec.  1065.610. Calculate the total reference work, Wref, as 
described in Sec.  1065.650. Divide the reference work by the duty 
cycle's time interval, [Delta]tdutycycle, to determine mean 
reference power, pref.
    (ii) Based on your engine design, estimate maximum power, 
Pmax, the design speed at maximum power, 
[fnof]nmax, the design maximum intake manifold boost 
pressure, Pinmax, and temperature, Tinmax. Also, 
estimate a mean fraction of power that is lost due to friction and 
pumping, Pfrict. Use this information along with the engine 
displacement volume, Vdisp, an approximate volumetric 
efficiency, [eta]V, and the number of engine strokes per 
power stroke (two-stroke or four-stroke), Nstroke, to 
estimate the maximum raw exhaust molar flow rate, nexhmax.
    (iii) Use your estimated values as described in the following 
example calculation:

    [GRAPHIC] [TIFF OMITTED] TR29JN21.205
    
                                Example:

eNOX = 2.5 g/(kW[middot]hr)
Wref = 11.883 kW[middot]hr
MNOX = 46.0055 g/mol = 46.0055[middot]10-\6\ g/[micro]mol
[Delta]tdutycycle = 20 min = 1200 s
Pref = 35.65 kW
Pfrict = 15%
Pmax = 125 kW
pmax = 300 kPa = 300000 Pa
Vdisp = 3.0 l = 0.0030 m\3\/r
fnmax = 2800 r/min = 46.67 r/s
Nstroke = 4
[eta]V = 0.9
R = 8.314472 J/(mol[middot]K)
Tmax = 348.15 K

[[Page 187]]

[GRAPHIC] [TIFF OMITTED] TR29JN21.206

    (2) To estimate the flow-weighted mean NMHC concentration in a CVS 
from a naturally aspirated nonroad spark-ignition engine at an NMHC 
standard of 0.5 g/(kW[middot]hr), you may do the following:
    (i) Based on your engine design, approximate a map of maximum torque 
versus speed and use it with the applicable normalized duty cycle in the 
standard-setting part to generate a reference duty cycle as described in 
Sec.  1065.610. Calculate the total reference work, Wref, as 
described in Sec.  1065.650.
    (ii) Multiply your CVS total molar flow rate by the time interval of 
the duty cycle, [Delta]tdutycycle. The result is the total 
diluted exhaust flow of the ndexh.
    (iii) Use your estimated values as described in the following 
example calculation:

    [GRAPHIC] [TIFF OMITTED] TR29JN21.207
    
                                Example:

eNMHC = 1.5 g/(kW[middot]hr)
Wref = 5.389 kW[middot]hr
MNMHC = 13.875389 g/mol = 13.875389[middot]10-\6\ g/
[micro]mol
ndexh = 6.021 mol/s
[Delta]tdutycycle = 30 min = 1800 s
[GRAPHIC] [TIFF OMITTED] TR29JN21.208


[[Page 188]]


XNMHC = 53.8 [micro]mol/mol

[86 FR 34548, June 29, 2021; 87 FR 64865, Oct. 26, 2022]



Sec.  1065.610  Duty cycle generation.

    This section describes how to generate duty cycles that are specific 
to your engine, based on the normalized duty cycles in the standard-
setting part. During an emission test, use a duty cycle that is specific 
to your engine to command engine speed, torque, and power, as 
applicable, using an engine dynamometer and an engine operator demand. 
Paragraphs (a) and (b) of this section describe how to ``normalize'' 
your engine's map to determine the maximum test speed or torque for your 
engine. The rest of this section describes how to use these values to 
``denormalize'' the duty cycles in the standard-setting parts, which are 
all published on a normalized basis. Thus, the term ``normalized'' in 
paragraphs (a) and (b) of this section refers to different values than 
it does in the rest of the section.
    (a) Maximum test speed, [fnof]ntest. For variable-speed engines, 
determine [fnof]ntest from the torque and power maps, 
generated according to Sec.  1065.510, as follows:
    (1) Determine a measured value for [fnof]ntest as 
follows:
    (i) Determine maximum power, Pmax, from the engine map 
generated according to Sec.  1065.510 and calculate the value for power 
equal to 98% of Pmax.
    (ii) Determine the lowest and highest engine speeds corresponding to 
98% of Pmax, using linear interpolation, and no 
extrapolation, as appropriate.
    (iii) Determine the engine speed corresponding to maximum power, 
fnPmax, by calculating the average of the two speed values 
from paragraph (a)(1)(ii) of this section. If there is only one speed 
where power is equal to 98% of Pmax, take fnPmax 
as the speed at which Pmax occurs.
    (iv) Transform the map into a normalized power-versus-speed map by 
dividing power terms by Pmax and dividing speed terms by 
fnPmax. Use the following equation to calculate a quantity 
representing the sum of squares from the normalized map:
[GRAPHIC] [TIFF OMITTED] TR29JN21.209

Where:

i = an indexing variable that represents one recorded value of an engine 
          map.
fnnormi = an engine speed normalized by dividing it by 
          fnPmax.
Pnormi = an engine power normalized by dividing it by 
          Pmax.
    (v) Determine the maximum value for the sum of the squares from the 
map and multiply that value by 0.98.
    (vi) Determine the lowest and highest engine speeds corresponding to 
the value calculated in paragraph (a)(1)(v) of this section, using 
linear interpolation as appropriate. Calculate fntest as the 
average of these two speed values. If there is only one speed 
corresponding to the value calculated in paragraph (a)(1)(v) of this 
section, take fntest as the speed where the maximum of the 
sum of the squares occurs.
    (vii) The following example illustrates a calculation of 
fntest:

    Pmax = 230.0

(fn1 = 2360, P1 = 222.5, fnnorm1 = 
          1.002, Pnorm1 = 0.9675)
(fn2 = 2364, P2 = 226.8, fnnorm2 = 
          1.004, Pnorm2 = 0.9859)
(fn3 = 2369, P3 = 228.6, fnnorm3 = 
          1.006, Pnorm3 = 0.9940)
(fn4 = 2374, P4 = 218.7, fnnorm4 = 
          1.008, Pnorm4 = 0.9508)
Sum of squares = (1.002\2\ + 0.9675\2\) = 1.94
Sum of squares = (1.004\2\ + 0.9859\2\) = 1.98
Sum of squares = (1.006\2\ + 0.9940\2\) = 2.00
Sum of squares = (1.008\2\ + 0.9508\2\) = 1.92

[[Page 189]]

[GRAPHIC] [TIFF OMITTED] TR19FE15.022

    (2) For engines with a high-speed governor that will be subject to a 
reference duty cycle that specifies normalized speeds greater than 100%, 
calculate an alternate maximum test speed, fntest,alt, as 
specified in this paragraph (a)(2). If fntest,alt is less 
than the measured maximum test speed, fntest, determined in 
paragraph (a)(1) of this section, replace fntest with 
fntest,alt. In this case, fntest,alt becomes the 
``maximum test speed'' for that engine for all duty cycles. Note that 
Sec.  1065.510 allows you to apply an optional declared maximum test 
speed to the final measured maximum test speed determined as an outcome 
of the comparison between fntest, and fntest,alt 
in this paragraph (a)(2). Determine fntest,alt as follows:
[GRAPHIC] [TIFF OMITTED] TR25OC16.160

Where:

fntest,alt = alternate maximum test speed
fnhi,idle = warm high-idle speed
fnidle = warm idle speed
% speedmax = maximum normalized speed from duty cycle
    Example: 
fnhi,idle = 2200 r/min
fnidle = 800 r/min
[GRAPHIC] [TIFF OMITTED] TR25OC16.161

fntest,alt = 2133 r/min

    (3) Transform normalized speeds to reference speeds according to 
paragraph (c) of this section by using the measured maximum test speed 
determined according to paragraphs (a)(1) and (2) of this section--or 
use your declared maximum test speed, as allowed in Sec.  1065.510.
    (b) Maximum test torque, Ttest. For constant-speed engines, 
determine Ttest from the torque and power-versus-speed maps, 
generated according to Sec.  1065.510, as follows:

[[Page 190]]

    (1) For constant speed engines mapped using the methods in Sec.  
1065.510(d)(5)(i) or (ii), determine a measured value for 
Ttest as follows:
    (i) Determine maximum power, Pmax, from the engine map 
generated according to Sec.  1065.510 and calculate the value for power 
equal to 98% of Pmax.
    (ii) Determine the lowest and highest engine speeds corresponding to 
98% of Pmax, using linear interpolation, and no 
extrapolation, as appropriate.
    (iii) Determine the engine speed corresponding to maximum power, 
fnPmax, by calculating the average of the two speed values 
from paragraph (a)(1)(ii) of this section. If there is only one speed 
where power is equal to 98% of Pmax, take fnPmax 
as the speed at which Pmax occurs.
    (iv) Transform the map into a normalized power-versus-speed map by 
dividing power terms by Pmax and dividing speed terms by 
fnPmax. Use Eq. 1065.610-1 to calculate a quantity 
representing the sum of squares from the normalized map.
    (v) Determine the maximum value for the sum of the squares from the 
map and multiply that value by 0.98.
    (vi) Determine the lowest and highest engine speeds corresponding to 
the value calculated in paragraph (a)(1)(v) of this section, using 
linear interpolation as appropriate. Calculate fntest as the 
average of these two speed values. If there is only one speed 
corresponding to the value calculated in paragraph (a)(1)(v) of this 
section, take fntest as the speed where the maximum of the 
sum of the squares occurs.
    (vii) The measured Ttest is the mapped torque at 
fntest.
    (2) For constant speed engines using the two-point mapping method in 
Sec.  1065.510(d)(5)(iii), you may follow paragraph (a)(1) of this 
section to determine the measured Ttest, or you may use the 
measured torque of the second point as the measured Ttest 
directly.
    (3) Transform normalized torques to reference torques according to 
paragraph (d) of this section by using the measured maximum test torque 
determined according to paragraph (b)(1) or (2) of this section--or use 
your declared maximum test torque, as allowed in Sec.  1065.510.
    (c) Generating reference speed values from normalized duty cycle 
speeds. Transform normalized speed values to reference values as 
follows:
    (1) % speed. If your normalized duty cycle specifies % speed values, 
use your warm idle speed and your maximum test speed to transform the 
duty cycle, as follows:
[GRAPHIC] [TIFF OMITTED] TR25OC16.162

    Example: 
% speed = 85% = 0.85
fntest = 2364 r/min
fnidle = 650 r/min
fnref = 0.85  (2364-650) + 650
fnref = 2107 r/min

    (2) A, B, C, and D speeds. If your normalized duty cycle specifies 
speeds as A, B, C, or D values, use your power-versus-speed curve to 
determine the lowest speed below maximum power at which 50% of maximum 
power occurs. Denote this value as nlo. Take nlo 
to be warm idle speed if all power points at speeds below the maximum 
power speed are higher than 50% of maximum power. Also determine the 
highest speed above maximum power at which 70% of maximum power occurs. 
Denote this value as nhi. If all power points at speeds above 
the maximum power speed are higher than 70% of maximum power, take 
nhi to be the declared maximum safe engine speed or the 
declared maximum representative engine speed, whichever is lower. Use 
nhi and nlo to calculate reference values for A, 
B, C, or D speeds as follows:

[[Page 191]]

[GRAPHIC] [TIFF OMITTED] TR24JA23.106

                                Example:

nlo = 1005 r/min
nhi = 2385 r/min
[fnof]nrefA = 0.25 [middot] (2385 - 1005) + 1005
[fnof]nrefB = 0.50 [middot] (2385 - 1005) + 1005
[fnof]nrefC = 0.75 [middot] (2385 - 1005) + 1005
[fnof]nrefD = 0.15 [middot] (2385 - 1005) + 1005
[fnof]nrefA = 1350 r/min
[fnof]nrefB = 1695 r/min
[fnof]nrefC = 2040 r/min
[fnof]nrefD = 1212 r/min

    (3) Intermediate speed. Based on the map, determine maximum torque, 
Tmax, and the corresponding speed, fnTmax, 
calculated as the average of the lowest and highest speeds at which 
torque is equal to 98% of Tmax. Use linear interpolation 
between points to determine the speeds where torque is equal to 98% of 
Tmax. Identify your reference intermediate speed as one of 
the following values:
    (i) fnTmax if it is between (60 and 75) % of maximum test 
speed.
    (ii) 60% of maximum test speed if fnTmax is less than 60% 
of maximum test speed.
    (iii) 75% of maximum test speed if fnTmax is greater than 
75% of maximum test speed.
    (d) Generating reference torques from normalized duty-cycle torques. 
Transform normalized torques to reference torques using your map of 
maximum torque versus speed.
    (1) Reference torque for variable-speed engines. For a given speed 
point, multiply the corresponding % torque by the maximum torque at that 
speed, according to your map. If your engine is subject to a reference 
duty cycle that specifies negative torque values (i.e., engine 
motoring), use negative torque for those motoring points (i.e., the 
motoring torque). If you map negative torque as allowed under Sec.  
1065.510 (c)(2) and the low-speed governor activates, resulting in 
positive torques, you may replace those positive motoring mapped torques 
with negative values between zero and the largest negative motoring 
torque. For both maximum and motoring torque maps, linearly interpolate 
mapped torque values to determine torque between mapped speeds. If the 
reference speed is below the minimum mapped speed (i.e., 95% of idle 
speed or 95% of lowest required speed, whichever is higher), use the 
mapped torque at the minimum mapped speed as the reference torque. The 
result is the reference torque for each speed point.
    (2) Reference torque for constant-speed engines. Multiply a % torque 
value by your maximum test torque. The result is the reference torque 
for each point.
    (3) Required deviations. We require the following deviations for 
variable-speed engines intended primarily for propulsion of a vehicle 
with an automatic transmission where that engine is subject to a 
transient duty cycle with idle operation. These deviations are intended 
to produce a more representative transient duty cycle for these 
applications. For steady-state duty cycles or transient duty cycles with 
no idle operation, the requirements in this

[[Page 192]]

paragraph (d)(3) do not apply. Idle points for steady-state duty cycles 
of such engines are to be run at conditions simulating neutral or park 
on the transmission. You may develop different procedures for adjusting 
CITT as a function of speed, consistent with good engineering judgment.
    (i) Zero-percent speed is the warm idle speed measured according to 
Sec.  1065.510(b)(6) with CITT applied, i.e., measured warm idle speed 
in drive.
    (ii) If the cycle begins with a set of contiguous idle points (zero-
percent speed, and zero-percent torque), leave the reference torques set 
to zero for this initial contiguous idle segment. This is to represent 
free idle operation with the transmission in neutral or park at the 
start of the transient duty cycle, after the engine is started. If the 
initial idle segment is longer than 24 seconds, change the reference 
torques for the remaining idle points in the initial contiguous idle 
segment to CITT (i.e., change idle points corresponding to 25 seconds to 
the end of the initial idle segment to CITT). This is to represent 
shifting the transmission to drive.
    (iii) For all other idle points, change the reference torque to 
CITT. This is to represent the transmission operating in drive.
    (iv) If the engine is intended primarily for automatic transmissions 
with a Neutral-When-Stationary feature that automatically shifts the 
transmission to neutral after the vehicle is stopped for a designated 
time and automatically shifts back to drive when the operator increases 
demand (i.e., pushes the accelerator pedal), change the reference torque 
back to zero for idle points in drive after the designated time.
    (v) For all points with normalized speed at or below zero percent 
and reference torque from zero to CITT, set the reference torque to 
CITT. This is to provide smoother torque references below idle speed.
    (vi) For motoring points, make no changes.
    (vii) For consecutive points with reference torques from zero to 
CITT that immediately follow idle points, change their reference torques 
to CITT. This is to provide smooth torque transition out of idle 
operation. This does not apply if the Neutral-When-Stationary feature is 
used and the transmission has shifted to neutral.
    (viii) For consecutive points with reference torque from zero to 
CITT that immediately precede idle points, change their reference 
torques to CITT. This is to provide smooth torque transition into idle 
operation.
    (4) Permissible deviations for any engine. If your engine does not 
operate below a certain minimum torque under normal in-use conditions, 
you may use a declared minimum torque as the reference value instead of 
any value denormalized to be less than the declared value. For example, 
if your engine is connected to a hydrostatic transmission and it has a 
minimum torque even when all the driven hydraulic actuators and motors 
are stationary and the engine is at idle, then you may use this declared 
minimum torque as a reference torque value instead of any reference 
torque value generated under paragraph (d)(1) or (2) of this section 
that is between zero and this declared minimum torque.
    (e) Generating reference power values from normalized duty cycle 
powers. Transform normalized power values to reference speed and power 
values using your map of maximum power versus speed.
    (1) First transform normalized speed values into reference speed 
values. For a given speed point, multiply the corresponding % power by 
the mapped power at maximum test speed, fntest, unless 
specified otherwise by the standard-setting part. The result is the 
reference power for each speed point, Pref. Convert these 
reference powers to corresponding torques for operator demand and 
dynamometer control and for duty cycle validation per 1065.514. Use the 
reference speed associated with each reference power point for this 
conversion. As with cycles specified with % torque, linearly interpolate 
between these reference torque values generated from cycles with % 
power.
    (2) Permissible deviations for any engine. If your engine does not 
operate below a certain power under normal in-use conditions, you may 
use a declared minimum power as the reference value instead of any value 
denormalized to be

[[Page 193]]

less than the declared value. For example, if your engine is directly 
connected to a propeller, it may have a minimum power called idle power. 
In this case, you may use this declared minimum power as a reference 
power value instead of any reference power value generated per paragraph 
(e)(1) of this section that is from zero to this declared minimum power.

[73 FR 37324, June 30, 2008, as amended at 73 FR 59330, Oct. 8, 2008; 75 
FR 23045, Apr. 30, 2010; 76 FR 57453, Sept. 15, 2011; 78 FR 36398, June 
17, 2013; 79 FR 23783, Apr. 28, 2014; 80 FR 9118, Feb. 19, 2015; 81 FR 
74170, Oct. 25, 2016; 86 FR 34555, June 29, 2021; 88 FR 4679, Jan. 24, 
2023]



Sec.  1065.630  Local acceleration of gravity.

    (a) The acceleration of Earth's gravity, ag, varies 
depending on the test location. Determine ag at your location 
by entering latitude, longitude, and elevation data into the U.S. 
National Oceanographic and Atmospheric Administration's surface gravity 
prediction website at https://geodesy.noaa.gov/cgi-bin /grav_pdx.prl.
    (b) If the website specified in paragraph (a) of this section is 
unavailable, or the test location is outside of the continental United 
States, you may calculate ag for your latitude as follows:
[GRAPHIC] [TIFF OMITTED] TR28AP14.143

Where:

u = Degrees north or south latitude.

    Example: 
u = 45[deg]
ag = 9.7803267715 [middot] (1 + 5.2790414 [middot] 
          10-3 [middot] sin\2\ (45) + 2.32718 [middot] 
          10-5 [middot] sin\4\ (45) + 1.262 [middot] 
          10-7 [middot] sin\6\ (45) + 7 [middot] 
          10-10 [middot] sin\8\ (45)
ag = 9.8061992026 m/s \2\

[79 FR 23784, Apr. 28, 2014, as amended at 88 FR 4680, Jan. 24, 2023]



Sec.  1065.640  Flow meter calibration calculations.

    This section describes the calculations for calibrating various flow 
meters. After you calibrate a flow meter using these calculations, use 
the calculations described in Sec.  1065.642 to calculate flow during an 
emission test. Paragraph (a) of this section first describes how to 
convert reference flow meter outputs for use in the calibration 
equations, which are presented on a molar basis. The remaining 
paragraphs describe the calibration calculations that are specific to 
certain types of flow meters.
    (a) Reference meter conversions. The calibration equations in this 
section use molar flow rate, nref, as a reference quantity. 
If your reference meter outputs a flow rate in a different quantity, 
such as standard volume rate,Vstdref, actual volume 
rate,Vactref, or mass rate, mref, convert your 
reference meter output to a molar flow rate using the following 
equations, noting that while values for volume rate, mass rate, 
pressure, temperature, and molar mass may change during an emission 
test, you should ensure that they are as constant as practical for each 
individual set point during a flow meter calibration:

[[Page 194]]

[GRAPHIC] [TIFF OMITTED] TR29JN21.210

Where:

nref = reference molar flow rate.
Vstdref = reference volume flow rate corrected to a standard 
          pressure and a standard temperature.
Vactref = reference volume flow rate at the actual pressure 
          and temperature of the flow rate.
mref = reference mass flow.
pstd = standard pressure.
pact = actual pressure of the flow rate.
Tstd = standard temperature.
Tact = actual temperature of the flow rate.
R = molar gas constant.
Mmix = molar mass of the flow rate.
    Example 1: 
Vstdref = 1000.00 ft\3/min\ = 0.471948 m\3/s\
pstd = 29.9213 in Hg @ 32 [deg]F = 101.325 kPa = 101325 Pa = 
          101325 kg/(m[middot]s\2\)
Tstd = 68.0 [deg]F = 293.15 K
R = 8.314472 J/(mol[middot]K) = 8.314472 (m\2\[middot]kg)/
          (s\2\[middot]mol[middot]K)
          [GRAPHIC] [TIFF OMITTED] TR29JN21.211
          
nref = 19.619 mol/s
    Example 2: 
mref = 17.2683 kg/min = 287.805 g/s
Mmix = 28.7805 g/mol
[GRAPHIC] [TIFF OMITTED] TR29JN21.212

nref = 10.0000 mol/s

    (b) PDP calibration calculations. Perform the following steps to 
calibrate a PDP flow meter:
    (1) Calculate PDP volume pumped per revolution, Vrev, for 
each restrictor position from the mean values determined in Sec.  
1065.340 as follows:
[GRAPHIC] [TIFF OMITTED] TR25OC16.169

Where:

nref = mean reference molar flow rate.
R = molar gas constant.
Tin = mean temperature at the PDP inlet.
Pin = mean static absolute pressure at the PDP inlet.
fnPDP = mean PDP speed.
    Example: 
nref = 25.096 mol/s
R = 8.314472 J/(mol[middot]K) = 8.314472 (m\2\[middot]kg)/
          (s\2\[middot]mol[middot]K)
Tin = 299.5 K
Pin = 98.290 kPa = 98290 Pa = 98290 kg/(m[middot]s\2\)
fnPDP = 1205.1 r/min = 20.085 r/s

[[Page 195]]

[GRAPHIC] [TIFF OMITTED] TR25OC16.170

Vrev = 0.03166 m\3\/r

    (2) Calculate a PDP slip correction factor, Ks, for each 
restrictor position from the mean values determined in Sec.  1065.340 as 
follows:
[GRAPHIC] [TIFF OMITTED] TR25OC16.171

Where:
fnPDP = mean PDP speed.
Pout = mean static absolute pressure at the PDP outlet.
Pin = mean static absolute pressure at the PDP inlet.
    Example: 
fnPDP = 1205.1 r/min = 20.085 r/s
Pout = 100.103 kPa
Pin = 98.290 kPa
[GRAPHIC] [TIFF OMITTED] TR25OC16.172

Ks = 0.006700 s/r

    (3) Perform a least-squares regression of Vrev, versus 
Ks, by calculating slope, a1, and intercept, 
a0, as described for a floating intercept in Sec.  1065.602.
    (4) Repeat the procedure in paragraphs (b)(1) through (3) of this 
section for every speed that you run your PDP.
    (5) The following table illustrates a range of typical values for 
different PDP speeds:

                           Table 1 of Sec.   1065.640--Example of PDP Calibration Data
----------------------------------------------------------------------------------------------------------------
                      fnPDP (revolution/s)                          a1 (m\3\/s)         a0 (m\3\/revolution)
----------------------------------------------------------------------------------------------------------------
12.6...........................................................              0.841                         0.056
16.5...........................................................              0.831                        -0.013
20.9...........................................................              0.809                         0.028
23.4...........................................................              0.788                        -0.061
----------------------------------------------------------------------------------------------------------------

    (6) For each speed at which you operate the PDP, use the appropriate 
regression equation from this paragraph (b) to calculate flow rate 
during emission testing as described in Sec.  1065.642.
    (c) Venturi governing equations and permissible assumptions. This 
section describes the governing equations and permissible assumptions 
for calibrating a venturi and calculating flow using a venturi. Because 
a subsonic venturi (SSV) and a critical-flow venturi (CFV) both operate 
similarly, their governing equations are nearly the same, except for the 
equation describing their pressure ratio, r (i.e., rSSV 
versus rCFV). These governing equations assume one-
dimensional isentropic

[[Page 196]]

inviscid flow of an ideal gas. Paragraph (c)(5) of this section 
describes other assumptions that may apply. If good engineering judgment 
dictates that you account for gas compressibility, you may either use an 
appropriate equation of state to determine values of Z as a function of 
measured pressure and temperature, or you may develop your own 
calibration equations based on good engineering judgment. Note that the 
equation for the flow coefficient, Cf, is based on the ideal 
gas assumption that the isentropic exponent, g, is equal to the ratio of 
specific heats, Cp/Cv. If good engineering 
judgment dictates using a real gas isentropic exponent, you may either 
use an appropriate equation of state to determine values of [gamma] as a 
function of measured pressures and temperatures, or you may develop your 
own calibration equations based on good engineering judgment.
    (1) Calculate molar flow rate, n, as follows:
    [GRAPHIC] [TIFF OMITTED] TR25OC16.173
    
Where:

    Cd = discharge coefficient, as determined in paragraph 
(c)(2) of this section.
    Cf = flow coefficient, as determined in paragraph (c)(3) 
of this section.
    At = venturi throat cross-sectional area.
    pin = venturi inlet absolute static pressure.
    Z = compressibility factor.
    Mmix = molar mass of gas mixture.
    R = molar gas constant.
    Tin = venturi inlet absolute temperature.

    (2) Using the data collected in Sec.  1065.340, calculate 
Cd for each flow rate using the following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.174

Where:

nref = a reference molar flow rate.

    (3) Determine Cf using one of the following methods:
    (i) For CFV flow meters only, determine CfCFV from the 
following table based on your values for [beta] and [gamma], using 
linear interpolation to find intermediate values:

   Table 2 of Sec.   1065.640-CfCFV Versus b and g for CFV Flow Meters
------------------------------------------------------------------------
                                  CfCFV
-------------------------------------------------------------------------
                                                   gdexh = gair = 1.399
           b                   gexh = 1.385
------------------------------------------------------------------------
            0.000                   0.6822                  0.6846
            0.400                   0.6857                  0.6881
            0.500                   0.6910                  0.6934
            0.550                   0.6953                  0.6977
            0.600                   0.7011                  0.7036
            0.625                   0.7047                  0.7072
            0.650                   0.7089                  0.7114
            0.675                   0.7137                  0.7163
            0.700                   0.7193                  0.7219
            0.720                   0.7245                  0.7271
            0.740                   0.7303                  0.7329
            0.760                   0.7368                  0.7395
            0.770                   0.7404                  0.7431

[[Page 197]]

 
            0.780                   0.7442                  0.7470
            0.790                   0.7483                  0.7511
            0.800                   0.7527                  0.7555
            0.810                   0.7573                  0.7602
            0.820                   0.7624                  0.7652
            0.830                   0.7677                  0.7707
            0.840                   0.7735                  0.7765
            0.850                   0.7798                  0.7828
------------------------------------------------------------------------

    (ii) For any CFV or SSV flow meter, you may use the following 
equation to calculate Cf for each flow rate:
[GRAPHIC] [TIFF OMITTED] TR25OC16.175

Where:

g = isentropic exponent. For an ideal gas, this is the ratio of specific 
          heats of the gas mixture, Cp/Cv.
r = pressure ratio, as determined in paragraph (c)(4) of this section.
b = ratio of venturi throat to inlet diameters.

    (4) Calculate r as follows:
    (i) For SSV systems only, calculate rSSV using the 
following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.176

Where:

[Delta]pSSV = Differential static pressure; venturi inlet 
          minus venturi throat.

    (ii) For CFV systems only, calculate rCFV iteratively 
using the following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.177


[[Page 198]]


    (5) You may apply any of the following simplifying assumptions or 
develop other values as appropriate for your test configuration, 
consistent with good engineering judgment:
    (i) For raw exhaust, diluted exhaust, and dilution air, you may 
assume that the gas mixture behaves as an ideal gas: Z = 1.
    (ii) For raw exhaust, you may assume g = 1.385.
    (iii) For diluted exhaust and dilution air, you may assume g = 
1.399.
    (iv) For diluted exhaust and dilution air, you may assume the molar 
mass of the mixture, Mmix, is a function only of the amount 
of water in the dilution air or calibration air, as follows:
[GRAPHIC] [TIFF OMITTED] TR25OC16.178

Where:

Mair = molar mass of dry air.
xH2O = amount of H2O in the dilution air or 
          calibration air, determined as described in Sec.  1065.645.
MH2O = molar mass of water.

    Example: 
Mair = 28.96559 g/mol
xH2O = 0.0169 mol/mol
MH2O = 18.01528 g/mol
Mmix = 28.96559 [middot] (1- 0.0169) + 18.01528 [middot] 
          0.0169
Mmix = 28.7805 g/mol

    (v) For diluted exhaust and dilution air, you may assume a constant 
molar mass of the mixture, Mmix, for all calibration and all 
testing as long as your assumed molar mass differs no more than 1% from the estimated minimum and maximum molar mass 
during calibration and testing.
    You may assume this, using good engineering judgment, if you 
sufficiently control the amount of water in calibration air and in 
dilution air or if you remove sufficient water from both calibration air 
and dilution air. The following table gives examples of permissible 
ranges of dilution air dewpoint versus calibration air dewpoint:

  Table 3 of Sec.   1065.640--Examples of Dilution Air and Calibration Air Dewpoints at Which You May Assume a
                                                  Constant Mmix
----------------------------------------------------------------------------------------------------------------
                                                                     assume the
                                                                     following       for the following ranges of
             If calibration Tdew ( [deg]C) is . . .              constant Mmix (g/      Tdew ( [deg]C) during
                                                                     mol) . . .          emission tests \a\
----------------------------------------------------------------------------------------------------------------
dry............................................................           28.96559                     dry to 18
0..............................................................           28.89263                     dry to 21
5..............................................................           28.86148                     dry to 22
10.............................................................           28.81911                     dry to 24
15.............................................................           28.76224                     dry to 26
20.............................................................           28.68685                      -8 to 28
25.............................................................           28.58806                      12 to 31
30.............................................................           28.46005                      23 to 34
----------------------------------------------------------------------------------------------------------------
\a\ Range valid for all calibration and emission testing over the atmospheric pressure range (80.000 to 103.325)
  kPa.

    (6) The following example illustrates the use of the governing 
equations to calculate Cd of an SSV flow meter at one 
reference flow meter value. Note that calculating Cd for a 
CFV flow meter would be similar, except that Cf would be 
determined from Table 2 of this section or calculated iteratively using 
values of b and g as described in paragraph (c)(2) of this section.

    Example: 
nref = 57.625 mol/s
Z = 1
Mmix = 28.7805 g/mol = 0.0287805 kg/mol
R = 8.314472 J/(mol [middot] K) = 8.314472 (m\2\ [middot] kg)/(s\2\ 
          [middot] mol [middot] K)
Tin = 298.15 K
At = 0.01824 m\2\
pin = 99.132 kPa = 99132.0 Pa = 99132 kg/(m[middot]s\2\)
g = 1.399
b = 0.8
[Delta]p = 2.312 kPa

[[Page 199]]

[GRAPHIC] [TIFF OMITTED] TR25OC16.179

Cf = 0.274
[GRAPHIC] [TIFF OMITTED] TR25OC16.314

Cd = 0.982

    (d) SSV calibration. Perform the following steps to calibrate an SSV 
flow meter:
    (1) Calculate the Reynolds number, Re#, for each 
reference molar flow rate, nref, using the throat diameter of 
the venturi, dt. Because the dynamic viscosity, [micro], is 
needed to compute Re#, you may use your own fluid viscosity 
model to determine [micro] for your calibration gas (usually air), using 
good engineering judgment. Alternatively, you may use the Sutherland 
three-coefficient viscosity model to approximate [micro], as shown in 
the following sample calculation for Re#:
[GRAPHIC] [TIFF OMITTED] TR29JN21.213

    Where, using the Sutherland three-coefficient viscosity model as 
captured in Table 4 of this section:
[GRAPHIC] [TIFF OMITTED] TR29JN21.214

Where:

[micro]0 = Sutherland reference viscosity.
T0 = Sutherland reference temperature.
S = Sutherland constant.

[[Page 200]]



               Table 4 of Sec.   1065.640--Sutherland Three-Coefficient Viscosity Model Parameters
----------------------------------------------------------------------------------------------------------------
                                       [micro]0          T0           S        Temperature range  Pressure limit
                                   ------------------------------------------    within 2% ---------------
              Gas \a\                    (kg/                                      error \b\
                                     (m[middot]s))      (K)          (K)     --------------------      (kPa)
                                                                                      (K)
----------------------------------------------------------------------------------------------------------------
Air...............................  1.716[middot]1          273          111       170 to 1900            <=1800
                                               0-5
CO2...............................  1.370[middot]1          273          222       190 to 1700            <=3600
                                               0-5
H2O...............................  1.12[middot]10-         350         1064       360 to 1500           <=10000
                                                 5
O2................................  1.919[middot]1          273          139       190 to 2000            <=2500
                                               0-5
N2................................  1.663[middot]1          273          107       100 to 1500            <=1600
                                               0-5
----------------------------------------------------------------------------------------------------------------
\a\ Use tabulated parameters only for the pure gases, as listed. Do not combine parameters in calculations to
  calculate viscosities of gas mixtures.
\b\ The model results are valid only for ambient conditions in the specified ranges.

    Example: 
[micro]0 = 1.716[middot]10-5 kg/(m[middot]s)
T0 = 273 K
S = 111 K
[GRAPHIC] [TIFF OMITTED] TR29JN21.215

[micro] = 1.838[middot]10-5 kg/(m[middot]s)
Mmix = 28.7805 g/mol = 0.0287805 kg/mol
nref = 57.625 mol/s
dt = 152.4 mm = 0.1524 m
Tin = 298.15 K
[GRAPHIC] [TIFF OMITTED] TR29JN21.216

Re# = 7.538[middot]10\5\

    (2) Create an equation for Cd as a function of 
Re#, using paired values of the two quantities. The equation 
may involve any mathematical expression, including a polynomial or a 
power series. The following equation is an example of a commonly used 
mathematical expression for relating Cd and Re#:
[GRAPHIC] [TIFF OMITTED] TR25OC16.183

    (3) Perform a least-squares regression analysis to determine the 
best-fit coefficients for the equation and calculate SEE as described in 
Sec.  1065.602. When using Eq. 1065.640-12, treat Cd as y and 
the radical term as yref and use Eq. 1065.602-12 to calculate 
SEE. When using another mathematical expression, use the same approach 
to substitute that expression into the numerator of Eq. 1065.602-12 and 
replace the 2 in the denominator with the number of coefficients in the 
mathematical expression.

[[Page 201]]

    (4) If the equation meets the criterion of SEE <= 0.5% [middot] 
Cdmax, you may use the equation for the corresponding range 
of Re#, as described in Sec.  1065.642.
    (5) If the equation does not meet the specified statistical 
criterion, you may use good engineering judgment to omit calibration 
data points; however you must use at least seven calibration data points 
to demonstrate that you meet the criterion. For example, this may 
involve narrowing the range of flow rates for a better curve fit.
    (6) Take corrective action if the equation does not meet the 
specified statistical criterion even after omitting calibration data 
points. For example, select another mathematical expression for the 
Cd versus Re# equation, check for leaks, or repeat 
the calibration process. If you must repeat the calibration process, we 
recommend applying tighter tolerances to measurements and allowing more 
time for flows to stabilize.
    (7) Once you have an equation that meets the specified statistical 
criterion, you may use the equation only for the corresponding range of 
Re#.
    (e) CFV calibration. Some CFV flow meters consist of a single 
venturi and some consist of multiple venturis, where different 
combinations of venturis are used to meter different flow rates. For CFV 
flow meters that consist of multiple venturis, either calibrate each 
venturi independently to determine a separate discharge coefficient, 
Cd, for each venturi, or calibrate each combination of 
venturis as one venturi. In the case where you calibrate a combination 
of venturis, use the sum of the active venturi throat areas as 
At, the square root of the sum of the squares of the active 
venturi throat diameters as dt, and the ratio of the venturi 
throat to inlet diameters as the ratio of the square root of the sum of 
the active venturi throat diameters (dt) to the diameter of 
the common entrance to all the venturis. (D). To determine the 
Cd for a single venturi or a single combination of venturis, 
perform the following steps:
    (1) Use the data collected at each calibration set point to 
calculate an individual Cd for each point using Eq. 1065.640-
4.
    (2) Calculate the mean and standard deviation of all the 
Cd values according to Eqs. 1065.602-1 and 1065.602-2.
    (3) If the standard deviation of all the Cd values is 
less than or equal to 0.3% of the mean Cd, use the mean 
Cd in Eq. 1065.642-4, and use the CFV only up to the highest 
venturi pressure ratio, r, measured during calibration using the 
following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.184

Where:

[Delta]pCFV = Differential static pressure; venturi inlet 
          minus venturi outlet.

    (4) If the standard deviation of all the Cd values 
exceeds 0.3% of the mean Cd, omit the Cd value 
corresponding to the data point collected at the highest r measured 
during calibration.
    (5) If the number of remaining data points is less than seven, take 
corrective action by checking your calibration data or repeating the 
calibration process. If you repeat the calibration process, we recommend 
checking for leaks, applying tighter tolerances to measurements and 
allowing more time for flows to stabilize.
    (6) If the number of remaining Cd values is seven or 
greater, recalculate the mean and standard deviation of the remaining 
Cd values.
    (7) If the standard deviation of the remaining Cd values 
is less than or equal to 0.3% of the mean of the remaining 
Cd, use that mean Cd in Eq. 1065.642-4, and use 
the CFV values only up to the

[[Page 202]]

highest r associated with the remaining Cd.
    (8) If the standard deviation of the remaining Cd still 
exceeds 0.3% of the mean of the remaining Cd values, repeat 
the steps in paragraph (e)(4) through (8) of this section.

[79 FR 23785, Apr. 28, 2014, as amended at 81 FR 74172, Oct. 25, 2016; 
86 FR 34556, June 29, 2021]



Sec.  1065.642  PDP, SSV, and CFV molar flow rate calculations.

    This section describes the equations for calculating molar flow 
rates from various flow meters. After you calibrate a flow meter 
according to Sec.  1065.640, use the calculations described in this 
section to calculate flow during an emission test.
    (a) PDP molar flow rate. (1) Based on the speed at which you operate 
the PDP for a test interval, select the corresponding slope, 
a1, and intercept, a0, as calculated in Sec.  
1065.640, to calculate PDP molar flow rate,, as follows:
[GRAPHIC] [TIFF OMITTED] TR25OC16.185

Where:

fnPDP = pump speed.
Vrev = PDP volume pumped per revolution, as determined in 
          paragraph (a)(2) of this section.
pin = static absolute pressure at the PDP inlet.
R = molar gas constant.
Tin = absolute temperature at the PDP inlet.

    (2) Calculate Vrev using the following equation:
    [GRAPHIC] [TIFF OMITTED] TR25OC16.186
    
pout = static absolute pressure at the PDP outlet.
    Example: 
a1 = 0.8405 (m\3\/s)
fnPDP = 12.58 r/s
Pout = 99.950 kPa
Pin = 98.575 kPa = 98575 Pa = 98575 kg/(m[middot]s\2\)
a0 = 0.056 (m\3\/r)
R = 8.314472 J/(mol[middot]K) = 8.314472 (m\2\[middot]kg)/
          (s\2\[middot]mol[middot]K)
Tin = 323.5 K
[GRAPHIC] [TIFF OMITTED] TR25OC16.187

[GRAPHIC] [TIFF OMITTED] TR25OC16.188


[[Page 203]]


n = 29.428 mol/s

    (b) SSV molar flow rate. Calculate SSV molar flow rate, n, as 
follows:
[GRAPHIC] [TIFF OMITTED] TR29JN21.217

Where:

Cd = discharge coefficient, as determined based on the 
          Cd versus Re# equation in Sec.  
          1065.640(d)(2).
Cf = flow coefficient, as determined in Sec.  
          1065.640(c)(3)(ii).
At = venturi throat cross-sectional area.
pin = static absolute pressure at the venturi inlet.
Z = compressibility factor.
Mmix = molar mass of gas mixture.
R = molar gas constant.
Tin = absolute temperature at the venturi inlet.
    Example: 
At = 0.01824 m\2\
pin = 99.132 kPa = 99132 Pa = 99132 kg/(m[middot]s\2\)
Z = 1
Mmix = 28.7805 g/mol = 0.0287805 kg/mol
R = 8.314472 J/(mol[middot]K) = 8.314472 (m\2\[middot]kg)/
          (s\2\[middot]mol[middot]K)
Tin = 298.15 K
Re# = 7.232[middot]10\5\
[gamma] = 1.399
[beta] = 0.8
[Delta]p = 2.312 kPa

    Using Eq. 1065.640-7:

rssv = 0.997

    Using Eq. 1065.640-6:

Cf = 0.274

    Using Eq. 1065.640-5:

Cd = 0.990
[GRAPHIC] [TIFF OMITTED] TR29JN21.218

n = 58.173 mol/s

    (c) CFV molar flow rate. If you use multiple venturis and you 
calibrate each venturi independently to determine a separate discharge 
coefficient, Cd (or calibration coefficient, Kv), 
for each venturi, calculate the individual molar flow rates through each 
venturi and sum all their flow rates to determine CFV flow rate, n. If 
you use multiple venturis and you calibrated venturis in combination, 
calculate n using the sum of the active venturi throat areas as 
At, the square root of the sum of the squares of the active 
venturi throat diameters as dt, and the ratio of the venturi 
throat to inlet diameters as the ratio of the square root of the sum of 
the active venturi throat diameters (dt) to the diameter of 
the common entrance to all the venturis (D).
    (1) To calculate n through one venturi or one combination of 
venturis, use its respective mean Cd and other constants you 
determined according to Sec.  1065.640 and calculate n as follows:

[[Page 204]]

[GRAPHIC] [TIFF OMITTED] TR29JN21.219

Where:

Cf = flow coefficient, as determined in Sec.  1065.640(c)(3).
    Example: 
Cd = 0.985
Cf = 0.7219
At = 0.00456 m\2\
pin = 98.836 kPa = 98836 Pa = 98836 kg/(m[middot]s\2\)
Z = 1
Mmix = 28.7805 g/mol = 0.0287805 kg/mol
R = 8.314472 J/(mol[middot]K) = 8.314472 (m\2\[middot]kg)/
          (s\2\[middot]mol[middot]K)
Tin = 378.15 K
[GRAPHIC] [TIFF OMITTED] TR29JN21.220

n = 33.690 mol/s

    (2) To calculate the molar flow rate through one venturi or a 
combination of venturis, you may use its respective mean, Kv, 
and other constants you determined according to Sec.  1065.640 and 
calculate its molar flow rate n during an emission test. Note that if 
you follow the permissible ranges of dilution air dewpoint versus 
calibration air dewpoint in Table 3 of Sec.  1065.640, you may set 
Mmix-cal and Mmix equal to 1. Calculate n as 
follows:
[GRAPHIC] [TIFF OMITTED] TR25OC16.192

Where:
[GRAPHIC] [TIFF OMITTED] TR25OC16.193

Vstdref = volume flow rate of the standard at reference 
          conditions of 293.15 K and 101.325 kPa.
Tin-cal = venturi inlet temperature during calibration.
Pin-cal = venturi inlet pressure during calibration.
Mmix-cal = molar mass of gas mixture used during calibration.

[[Page 205]]

Mmix = molar mass of gas mixture during the emission test 
          calculated using Eq. 1065.640-9.

    Example: 
Vstdref = 0.4895 m\3\
Tin-cal = 302.52 K
Pin-cal = 99.654 kPa = 99654 Pa = 99654 kg/(m[middot]s\2\)
pin = 98.836 kPa = 98836 Pa = 98836 kg/(m[middot]s\2\)
pstd = 101.325 kPa = 101325 Pa = 101325 kg/(m[middot]s\2\)
Mmix-cal = 28.9656 g/mol = 0.0289656 kg/mol
Mmix = 28.7805 g/mol = 0.0287805 kg/mol
Tin = 353.15 K
Tstd = 293.15 K
R = 8.314472 J/(mol[middot]K) = 8.314472 (m\2\[middot]kg)/
          (s\2\[middot]mol[middot]K)
          [GRAPHIC] [TIFF OMITTED] TR25OC16.194
          
n = 16.457 mol/s

[81 FR 74177, Oct. 25, 2016, as amended at 86 FR 34557, June 29, 2021]



Sec.  1065.643  Carbon balance error verification calculations.

    This section describes how to calculate quantities used in the 
carbon balance error verification described in Sec.  1065.543. 
Paragraphs (a) through (c) of this section describe how to calculate the 
mass of carbon for a test interval from carbon-carrying fluid streams, 
intake air into the system, and exhaust emissions, respectively. 
Paragraph (d) of this section describes how to use these carbon masses 
to calculate four different quantities for evaluating carbon balance 
error. Use rectangular or trapezoidal integration methods to calculate 
masses and amounts over a test interval from continuously measured or 
calculated mass and molar flow rates.
    (a) Fuel and other fluids. Determine the mass of fuel, DEF, and 
other carbon-carrying fluid streams, other than intake air, flowing into 
the system, mfluidj, for each test interval. Note that Sec.  
1065.543 allows you to omit all flows other than fuel. You may determine 
the mass of DEF based on ECM signals for DEF flow rate. You may 
determine fuel mass during field testing based on ECM signals for fuel 
flow rate. Calculate the mass of carbon from the combined carbon-
carrying fluid streams flowing into the system as follows:
[GRAPHIC] [TIFF OMITTED] TR29JN21.221

Where:

j = an indexing variable that represents one carbon-carrying fluid 
          stream.
N = total number of carbon-carrying fluid streams into the system over 
          the test interval.
wC = carbon mass fraction of the carbon-carrying fluid stream 
          as determined in Sec.  1065.655(d).
mfluid = the mass of the carbon-carrying fluid stream 
          determined over the test interval.
    Example: 
N = 2
wCfuel = 0.869

[[Page 206]]

wCDEF = 0.065
mfuel = 1119.6 g
mDEF = 36.8 g
mCfluid = 0.869[middot]1119.6 + 0.065[middot]36.8 = 975.3 g

    (b) Intake air. Calculate the mass of carbon in the intake air, 
mCair, for each test interval using one of the methods in 
this paragraph (b). The methods are listed in order of preference. Use 
the first method where all the inputs are available for your test 
configuration. For methods that calculate mCair based on the 
amount of CO2 per mole of intake air, we recommend measuring 
intake air concentration, but you may calculate xCO2int using 
Eq. 1065.655-10 and letting xCO2intdry = 375 [micro]mol/mol.
    (1) Calculate mCair, using the following equation if you 
measure intake air flow:
[GRAPHIC] [TIFF OMITTED] TR29JN21.222

Where:

MC = molar mass of carbon.
nint = measured amount of intake air over the test interval.
xCO2int = amount of intake air CO2 per mole of 
          intake air.
    Example: 
MC = 12.0107 g/mol
nint = 62862 mol
xCO2int = 369 [micro]mol/mol = 0.000369 mol/mol
mCair = 12.0107[middot]62862[middot]0.000369 = 278.6 g

    (2) Calculate mCair, using the following equation if you 
measure or calculate raw exhaust flow and you calculate chemical balance 
terms:
[GRAPHIC] [TIFF OMITTED] TR29JN21.223

Where:

MC = molar mass of carbon.
nexh = calculated or measured amount of raw exhaust over the 
          test interval.
xH2Oexh = amount of H2O in exhaust per mole of 
          exhaust.
xCO2int = amount of intake air CO2 per mole of 
          intake air.
xdil/exhdry = amount of excess air per mole of dry exhaust. 
          Note that excess air and intake air have the same composition, 
          so xCO2dil = xCO2int and 
          xH2Odil = xH2Oint for the chemical 
          balance calculation for raw exhaust.
xint/exhdry = amount of intake air required to produce actual 
          combustion products per mole of dry exhaust.
    Example: 
MC = 12.0107 g/mol
nexh = 62862 mol
xH2Oexh = 0.034 mol/mol
xCO2int = 369 [micro]mol/mol = 0.000369 mol/mol
xdil/exhdry = 0.570 mol/mol
xint/exhdry = 0.465 mol/mol
mCair = 12.0107[middot]62862[middot](1 - 
          0.034)[middot]0.000369[middot](0.570 + 0.465) = 278.6 g

    (3) Calculate mCair, using the following equation if you 
measure raw exhaust flow:
[GRAPHIC] [TIFF OMITTED] TR29JN21.224


[[Page 207]]


Where:

MC = molar mass of carbon.
nexh = measured amount of raw exhaust over the test interval.
xCO2int = amount of intake air CO2 per mole of 
          intake air.
    Example: 
MC = 12.0107 g/mol
nexh = 62862 mol
xCO2int = 369 [micro]mol/mol = 0.000369 mol/mol
mCair = 12.0107[middot]62862[middot]0.000369 = 278.6 g

    (4) Calculate mCair, using the following equation if you 
measure diluted exhaust flow and dilution air flow:
[GRAPHIC] [TIFF OMITTED] TR29JN21.225

Where:

MC = molar mass of carbon.
ndexh = measured amount of diluted exhaust over the test 
          interval as determined in Sec.  1065.642.
ndil = measured amount of dilution air over the test interval 
          as determined in Sec.  1065.667(b).
xCO2int = amount of intake air CO2 per mole of 
          intake air.
    Example: 
MC = 12.0107 g/mol
ndexh = 942930 mol
ndil = 880068 mol
xCO2int = 369 [micro]mol/mol = 0.000369 mol/mol
mCair = 12.0107[middot](942930 - 880068)[middot]0.000369 = 
          278.6 g

    (5) Determined mCair based on ECM signals for intake air 
flow as described in paragraph (b)(1) of this section.
    (6) If you measure diluted exhaust, determine mCair as 
described in paragraph (b)(4) of this section using a calculated amount 
of dilution air over the test interval as determined in Sec.  
1065.667(d) instead of the measured amount of dilution air.
    (c) Exhaust emissions. Calculate the mass of carbon in exhaust 
emissions, mCexh, for each test interval as follows:
[GRAPHIC] [TIFF OMITTED] TR29JN21.226

Where:

MC = molar mass of carbon.
mCO2 = mass of CO2 over the test interval as 
          determined in Sec.  1065.650(c).
MCO2 = molar mass of carbon dioxide.
mCO = mass of CO over the test interval as determined in 
          Sec.  1065.650(c).
MCO = molar mass of carbon monoxide.
mTHC = mass of THC over the test interval as determined in 
          Sec.  1065.650(c).
MTHC = effective C1 molar mass of total 
          hydrocarbon as defined in Sec.  1065.1005(f)(2).
    Example: 
MC = 12.0107 g/mol
mCO2 = 4567 g
MCO2 = 44.0095 g/mol
mCO = 0.803 g
MCO = 28.0101 g/mol
mTHC = 0.537 g
MTHC = 13.875389 g/mol
[GRAPHIC] [TIFF OMITTED] TR29JN21.227


[[Page 208]]


    (d) Carbon balance error quantities. Calculate carbon balance error 
quantities as follows:
    (1) Calculate carbon mass absolute error, [epsi]aC, for a 
test interval as follows:
[GRAPHIC] [TIFF OMITTED] TR24JA23.107

Where:

mCexh = mass of carbon in exhaust emissions over the test 
          interval as determined in paragraph (d) of this section.
mCfluid = mass of carbon in all the carbon-carrying fluid 
          streams flowing into the system over the test interval as 
          determined in paragraph (a) of this section.
mCair = mass of carbon in the intake air flowing into the 
          system over the test interval as determined in paragraph (b) 
          of this section.

                                Example:

mCexh = 1247.2 g
mCfluid = 975.3 g
mCair = 278.6 g
[epsi]aC = 1247.2 - 975.3 - 278.6
[epsi]aC = -6.7 g

    (2) Calculate carbon mass rate absolute error, 
[epsi]aCrate, for a test interval as follows:
[GRAPHIC] [TIFF OMITTED] TR24JA23.108

Where:

t = duration of the test interval.

                                Example:

[epsi]aC = -6.7 g
    t = 1202.2 s = 0.3339 hr
    [GRAPHIC] [TIFF OMITTED] TR24JA23.109
    
[epsi]aCrate = -20.065 g/hr

    (3) Calculate carbon mass relative error, [epsi]rC, for a 
test interval as follows:
[GRAPHIC] [TIFF OMITTED] TR24JA23.110

                                Example:

[epsi]aC = -6.7 g
mCfluid = 975.3 g
mCair = 278.6 g

[[Page 209]]

[GRAPHIC] [TIFF OMITTED] TR24JA23.111

[epsi]rC = -0.0053

    (4) Calculate composite carbon mass relative error, 
[epsi]rCcomp, for a duty cycle with multiple test intervals 
as follows:
    (i) Calculate [epsi]rCcomp using the following equation:
    [GRAPHIC] [TIFF OMITTED] TR24JA23.112
    
Where:

i = an indexing variable that represents one test interval.
N = number of test intervals.
WF = weighting factor for the test interval as defined in the standard-
          setting part.
mCexh = mass of carbon in exhaust emissions over the test 
          interval as determined in paragraph (c) of this section.
mCfluid = mass of carbon in all the carbon-carrying fluid 
          streams that flowed into the system over the test interval as 
          determined in paragraph (a) of this section.
mCair = mass of carbon in the intake air that flowed into the 
          system over the test interval as determined in paragraph (b) 
          of this section.
t = duration of the test interval. For duty cycles with multiple test 
          intervals of a prescribed duration, such as cold-start and 
          hot-start transient cycles, set t = 1 for all test intervals. 
          For discrete-mode steady-state duty cycles with multiple test 
          intervals of varying duration, set t equal to the actual 
          duration of each test interval.

    (ii) The following example illustrates calculation of 
[epsi]rCcomp, for cold-start and hot-start transient cycles:

N = 2
WF1 = \1/7\
WF2 = \6/7\
mCexh1 = 1255.3 g
mCexh2 = 1247.2 g
mCfluid1 = 977.8 g
mCfluid2 = 975.3 g
mCair1 = 280.2 g
mCair2 = 278.6 g
[GRAPHIC] [TIFF OMITTED] TR24JA23.113

[epsi]rCcomp = -0.0049

    (iii) The following example illustrates calculation of 
[epsi]rCcomp for multiple test intervals with varying 
duration, such as discrete-mode steady-state duty cycles:

N = 2
WF1 = 0.85
WF2 = 0.15
mCexh1 = 2.873 g
mCexh2 = 0.125 g
mCfluid1 = 2.864 g
mCfluid2 = 0.095 g
mCair1 = 0.023 g
mCair2 = 0.024 g
t1 = 123 s
t2 = 306 s

[[Page 210]]

[GRAPHIC] [TIFF OMITTED] TR24JA23.114

[epsi]rCcomp = -0.0047

[86 FR 34557, June 29, 2021, as amended at 87 FR 64865, Oct. 26, 2022; 
88 FR 4680, Jan. 24, 2023]



Sec.  1065.644  Vacuum-decay leak rate.

    This section describes how to calculate the leak rate of a vacuum-
decay leak verification, which is described in Sec.  1065.345(e). Use 
the following equation to calculate the leak rate nleak, and 
compare it to the criterion specified in Sec.  1065.345(e):
[GRAPHIC] [TIFF OMITTED] TR28AP14.036

Where:

Vvac = geometric volume of the vacuum-side of the sampling 
          system.
R = molar gas constant.
p2 = vacuum-side absolute pressure at time t2.
T2 = vacuum-side absolute temperature at time t2.
p1 = vacuum-side absolute pressure at time t1.
T1 = vacuum-side absolute temperature at time t1.
t2 = time at completion of vacuum-decay leak verification 
          test.
t1 = time at start of vacuum-decay leak verification test.

    Example: 
Vvac = 2.0000 L = 0.00200 m\3\
R = 8.314472 J/(mol [middot] K) = 8.314472 (m\2\ [middot] kg)/(s\2\ 
          [middot] mol [middot] K)
p2 = 50.600 kPa = 50600 Pa = 50600 kg/(m [middot] s\2\)
T2 = 293.15 K
p1 = 25.300 kPa = 25300 Pa = 25300 kg/(m [middot] s\2\)
T1 = 293.15 K
t2 = 10:57:35 a.m.
t1 = 10:56:25 a.m.
[GRAPHIC] [TIFF OMITTED] TR28AP14.037

[GRAPHIC] [TIFF OMITTED] TR28AP14.038


[[Page 211]]



[79 FR 23795, Apr. 28, 2014]



Sec.  1065.645  Amount of water in an ideal gas.

    This section describes how to determine the amount of water in an 
ideal gas, which you need for various performance verifications and 
emission calculations. Use the equation for the vapor pressure of water 
in paragraph (a) of this section or another appropriate equation and, 
depending on whether you measure dewpoint or relative humidity, perform 
one of the calculations in paragraph (b) or (c) of this section. 
Paragraph (d) of this section provides an equation for determining 
dewpoint from relative humidity and dry bulb temperature measurements. 
The equations for the vapor pressure of water as presented in this 
section are derived from equations in ``Saturation Pressure of Water on 
the New Kelvin Temperature Scale'' (Goff, J.A., Transactions American 
Society of Heating and Air-Conditioning Engineers, Vol. 63, No. 1607, 
pages 347-354). Note that the equations were originally published to 
derive vapor pressure in units of atmospheres and have been modified to 
derive results in units of kPa by converting the last term in each 
equation.
    (a) Vapor pressure of water. Calculate the vapor pressure of water 
for a given saturation temperature condition, Tsat, as 
follows, or use good engineering judgment to use a different 
relationship of the vapor pressure of water to a given saturation 
temperature condition:
    (1) For humidity measurements made at ambient temperatures from (0 
to 100) [deg]C, or for humidity measurements made over super-cooled 
water at ambient temperatures from (-50 to 0) [deg]C, use the following 
equation:

[[Page 212]]

[GRAPHIC] [TIFF OMITTED] TR28AP14.039

    (2) For humidity measurements over ice at ambient temperatures from 
(-100 to 0) [deg]C, use the following equation:

[[Page 213]]

[GRAPHIC] [TIFF OMITTED] TR28AP14.040

    (b) Dewpoint. If you measure humidity as a dewpoint, determine the 
amount of water in an ideal gas, xH20, as follows:
[GRAPHIC] [TIFF OMITTED] TR30AP10.034

Where:

xH20 = amount of water in an ideal gas.
pH20 = water vapor pressure at the measured dewpoint, 
          Tsat = Tdew.
pabs = wet static absolute pressure at the location of your 
          dewpoint measurement.

    Example:  :
pabs = 99.980 kPa
Tsat = Tdew = 9.5 [deg]C
Using Eq. 1065.645-1,
pH20 = 1.186581 kPa
xH2O = 1.186581/99.980
xH2O = 0.011868 mol/mol

    (c) Relative humidity. If you measure humidity as a relative 
humidity, RH, determine the amount of water in an ideal gas, 
xH2O, as follows:

[[Page 214]]

[GRAPHIC] [TIFF OMITTED] TR25OC16.195

Where:

xH2O = amount of water in an ideal gas.
RH = relative humidity.
pH2O = water vapor pressure at 100% relative humidity at the 
          location of your relative humidity measurement, 
          Tsat = Tamb.
pabs = wet static absolute pressure at the location of your 
          relative humidity measurement.

    Example: 
RH = 50.77% = 0.5077
pabs = 99.980 kPa
Tsat = Tamb = 20 [deg]C
    Using Eq. 1065.645-1,
pH2O = 2.3371 kPa
xH2O = (0.5077 [middot] 2.3371)/99.980
xH2O = 0.011868 mol/mol

    (d) Dewpoint determination from relative humidity and dry bulb 
temperature. This paragraph (d) describes how to calculate dewpoint 
temperature from relative humidity, RH. This is based on ``ITS-90 
Formulations for Vapor Pressure, Frostpoint Temperature, Dewpoint 
Temperature, and Enhancement Factors in the Range -100 to + 100 [deg]C'' 
(Hardy, B., The Proceedings of the Third International Symposium on 
Humidity & Moisture, Teddington, London, England, April 1998). Calculate 
pH20sat as described in paragraph (a) of this section based 
on setting Tsat equal to Tamb. Calculate 
pH20scaled by multiplying pH20sat by RH. Calculate 
the dewpoint, Tdew, from pH20 using the following 
equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.196

Where:

ln(pH2O) = the natural log of pH2Oscaled, which is 
          the water vapor pressure scaled to the relative humidity at 
          the location of the relative humidity measurement, 
          Tsat = Tamb

    Example: 
RH = 39.61% = 0.3961
Tsat = Tamb = 20.00 [deg]C = 293.15K
    Using Eq. 1065.645-1,
pH2Osat = 2.3371 kPa
pH2Oscaled = (0.3961 [middot] 2.3371) = 0.925717 kPa = 
          925.717 Pa
          [GRAPHIC] [TIFF OMITTED] TR25OC16.197
          

[73 FR 37327, June 30, 2008, as amended at 73 FR 59331, Oct. 8, 2008; 75 
FR 23048, Apr. 30, 2010; 76 FR 57456, Sept. 15, 2011;79 FR 23796, Apr. 
28, 2014; 81 FR 74179, Oct. 25, 2016]



Sec.  1065.650  Emission calculations.

    (a) General. Calculate brake-specific emissions over each applicable 
duty cycle or test interval. For test intervals with zero work (or 
power), calculate the emission mass (or mass rate), but do not calculate 
brake-specific emissions. Unless specified otherwise, for the purposes 
of calculating and reporting emission mass (or mass rate), do not alter 
any negative values of measured or calculated quantities. You may 
truncate negative values in

[[Page 215]]

chemical balance quantities listed in Sec.  1065.655(c) to facilitate 
convergence. For duty cycles with multiple test intervals, refer to the 
standard-setting part for calculations you need to determine a composite 
result, such as a calculation that weights and sums the results of 
individual test intervals in a duty cycle. If the standard-setting part 
does not include those calculations, use the equations in paragraph (g) 
of this section. This section is written based on rectangular 
integration, where each indexed value (i.e., ``i'') 
represents (or approximates) the mean value of the parameter for its 
respective time interval, delta-t. You may also integrate continuous 
signals using trapezoidal integration consistent with good engineering 
judgment.
    (b) Brake-specific emissions over a test interval. We specify three 
alternative ways to calculate brake-specific emissions over a test 
interval, as follows:
    (1) For any testing, you may calculate the total mass of emissions, 
as described in paragraph (c) of this section, and divide it by the 
total work generated over the test interval, as described in paragraph 
(d) of this section, using the following equation:
[GRAPHIC] [TIFF OMITTED] TR30AP10.036

    Example: 
mNOx = 64.975 g
W = 25.783 kW [middot] hr
eNOx = 64.975/25.783
eNOx = 2.520 g/(kW [middot] hr)

    (2) For discrete-mode steady-state testing, you may calculate the 
brake-specific emissions over a test interval using the ratio of 
emission mass rate to power, as described in paragraph (e) of this 
section, using the following equation:
[GRAPHIC] [TIFF OMITTED] TR30AP10.037

    (3) For field testing, you may calculate the ratio of total mass to 
total work, where these individual values are determined as described in 
paragraph (f) of this section. You may also use this approach for 
laboratory testing, consistent with good engineering judgment. Good 
engineering judgment dictates that this method not be used if there are 
any work flow paths described in Sec.  1065.210 that cross the system 
boundary, other than the primary output shaft (crankshaft). This is a 
special case in which you use a signal linearly proportional to raw 
exhaust molar flow rate to determine a value proportional to total 
emissions. You then use the same linearly proportional signal to 
determine total work using a chemical balance of fuel, DEF, intake air, 
and exhaust as described in Sec.  1065.655, plus information about your 
engine's brake-specific fuel consumption. Under this method, flow meters 
need not meet accuracy specifications, but they must meet the applicable 
linearity and repeatability specifications in subpart D or J of this 
part. The result is a brake-specific emission value calculated as 
follows:
[GRAPHIC] [TIFF OMITTED] TR30AP10.038


[[Page 216]]


    Example: 
m = 805.5 g
W = 52.102 kW [middot] hr
eCO = 805.5/52.102
eCO = 2.520 g/(kW [middot] hr)

    (c) Total mass of emissions over a test interval. To calculate the 
total mass of an emission, multiply a concentration by its respective 
flow. For all systems, make preliminary calculations as described in 
paragraph (c)(1) of this section to correct concentrations. Next, use 
the method in paragraphs (c)(2) through (4) of this section that is 
appropriate for your system. Finally, if necessary, calculate the mass 
of NMHC as described in paragraph (c)(5) of this section for all 
systems. Calculate the total mass of emissions as follows:
    (1) Concentration corrections. Perform the following sequence of 
preliminary calculations on recorded concentrations:
    (i) Use good engineering judgment to time-align flow and 
concentration data to match transformation time, t50, to 
within 1 s.
    (ii) Correct all gaseous emission analyzer concentration readings, 
including continuous readings, sample bag readings, and dilution air 
background readings, for drift as described in Sec.  1065.672. Note that 
you must omit this step where brake-specific emissions are calculated 
without the drift correction for performing the drift validation 
according to Sec.  1065.550(b). When applying the initial THC and 
CH4 contamination readings according to Sec.  1065.520(f), 
use the same values for both sets of calculations. You may also use as-
measured values in the initial set of calculations and corrected values 
in the drift-corrected set of calculations as described in Sec.  
1065.520(f)(7).
    (iii) Correct all THC and CH4 concentrations for initial 
contamination as described in Sec.  1065.660(a), including continuous 
readings, sample bags readings, and dilution air background readings.
    (iv) Correct all concentrations measured on a ``dry'' basis to a 
``wet'' basis, including dilution air background concentrations, as 
described in Sec.  1065.659.
    (v) Calculate all NMHC and CH4 concentrations, including 
dilution air background concentrations, as described in Sec.  1065.660.
    (vi) For emission testing with an oxygenated fuel, calculate any HC 
concentrations, including dilution air background concentrations, as 
described in Sec.  1065.665. See subpart I of this part for testing with 
oxygenated fuels.
    (vii) Correct all the NOX concentrations, including 
dilution air background concentrations, for intake-air humidity as 
described in Sec.  1065.670.
    (2) Continuous sampling. For continuous sampling, you must 
frequently record a continuously updated concentration signal. You may 
measure this concentration from a changing flow rate or a constant flow 
rate (including discrete-mode steady-state testing), as follows:
    (i) Varying flow rate. If you continuously sample from a varying 
exhaust flow rate, time align and then multiply concentration 
measurements by the flow rate from which you extracted it. We consider 
the following to be examples of varying flows that require a continuous 
multiplication of concentration times molar flow rate: raw exhaust, 
exhaust diluted with a constant flow rate of dilution air, and CVS 
dilution with a CVS flow meter that does not have an upstream heat 
exchanger or electronic flow control. This multiplication results in the 
flow rate of the emission itself. Integrate the emission flow rate over 
a test interval to determine the total emission. If the total emission 
is a molar quantity, convert this quantity to a mass by multiplying it 
by its molar mass, M. The result is the mass of the emission, m. 
Calculate m for continuous sampling with variable flow using the 
following equations:

[[Page 217]]

[GRAPHIC] [TIFF OMITTED] TR24JA23.115

Where:
[GRAPHIC] [TIFF OMITTED] TR24JA23.116

                                Example:

MNMHC = 13.875389 g/mol
N = 1200
xNMHC1 = 84.5 [micro]mol/mol = 84.5 [middot] 
10-\6\ mol/mol
xNMHC2 = 86.0 [micro]mol/mol = 86.0 [middot] 
10-\6\ mol/mol
nexh1 = 2.876 mol/s
nexh2 = 2.224 mol/s
[fnof]record = 1 Hz

    Using Eq. 1065.650-5,

[Delta]t = 1/1 = 1 s
mNMHC = 13.875389 [middot] (84.5 [middot] 10-\6\ 
[middot] 2.876 + 86.0 [middot] 10-\6\ [middot] 2.224 + . . . 
+ xNMHC1200 [middot] nexh) [middot] 1
mNMHC = 25.23 g

    (ii) Constant flow rate. If you continuously sample from a constant 
exhaust flow rate, use the same emission calculations described in 
paragraph (c)(2)(i) of this section or calculate the mean or flow-
weighted concentration recorded over the test interval and treat the 
mean as a batch sample, as described in paragraph (c)(3)(ii) of this 
section. We consider the following to be examples of constant exhaust 
flows: CVS diluted exhaust with a CVS flowmeter that has either an 
upstream heat exchanger, electronic flow control, or both.
    (3) Batch sampling. For batch sampling, the concentration is a 
single value from a proportionally extracted batch sample (such as a 
bag, filter, impinger, or cartridge). In this case, multiply the mean 
concentration of the batch sample by the total flow from which the 
sample was extracted. You may calculate total flow by integrating a 
varying flow rate or by determining the mean of a constant flow rate, as 
follows:
    (i) Varying flow rate. If you collect a batch sample from a varying 
exhaust flow rate, extract a sample proportional to the varying exhaust 
flow rate. We consider the following to be examples of varying flows 
that require proportional sampling: raw exhaust, exhaust diluted with a 
constant flow rate of dilution air, and CVS dilution with a CVS flow 
meter that does not have an upstream heat exchanger or electronic flow 
control. Integrate the flow rate over a test interval to determine the 
total flow from which you extracted the proportional sample. Multiply 
the mean concentration of the batch sample by the total flow from which 
the sample was extracted to determine the total emission. If the total 
emission is a molar quantity, convert this quantity to a mass by 
multiplying it by its molar mass, M. The result is the total emission 
mass, m. In the case of PM emissions, where the mean PM concentration is 
already in units of mass per mole of exhaust, simply multiply it by the 
total flow. The result is the total mass of PM, mPM. 
Calculate m for each constituent as follows:
    (A) Calculate m for measuring gaseous emission constituents with 
sampling that results in a molar concentration, x, using the following 
equation:

[[Page 218]]

[GRAPHIC] [TIFF OMITTED] TR24JA23.117

                                Example:

MNOX = 46.0055 g/mol
N = 9000
x = 85.6 [micro]mol/mol = 85.6 [middot] 10-\6\ mol/mol
ndexh1 = 25.534 mol/s
ndexh2 = 26.950 mol/s
[fnof]record = 5 Hz

    Using Eq. 1065.650-5:

[Delta]t = 1/5 = 0.2 s
mNOX 46.0055 [middot] 85.6 [middot] 10-\6\ 
[middot] (25.534 + 26.950+ . . . +
nexh9000) [middot] 0.2
mNOX = 4.201 g
    (B) Calculate m for sampling PM or any other analysis of a batch 
sample that yields a mass per mole of exhaust, M, using the following 
equation:
[GRAPHIC] [TIFF OMITTED] TR24JA23.118

    (ii) Proportional or constant flow rate. If you batch sample from a 
constant exhaust flow rate, extract a sample at a proportional or 
constant flow rate. We consider the following to be examples of constant 
exhaust flows: CVS diluted exhaust with a CVS flow meter that has either 
an upstream heat exchanger, electronic flow control, or both. Determine 
the mean molar flow rate from which you extracted the sample. Multiply 
the mean concentration of the batch sample by the mean molar flow rate 
of the exhaust from which the sample was extracted to determine the 
total emission and multiply the result by the time of the test interval. 
If the total emission is a molar quantity, convert this quantity to a 
mass by multiplying it by its molar mass, M. The result is the total 
emission mass, m. In the case of PM emissions, where the mean PM 
concentration is already in units of mass per mole of exhaust, simply 
multiply it by the total flow, and the result is the total mass of PM, 
mPM. Calculate m for each constituent as follows:
    (A) Calculate m for measuring gaseous emission constituents with 
sampling that results in a molar concentration, x, using the following 
equation:
[GRAPHIC] [TIFF OMITTED] TR24JA23.119

    (B) Calculate m for sampling PM or any other analysis of a batch 
sample that yields a mass per mole of exhaust, M, using the following 
equation:

[[Page 219]]

[GRAPHIC] [TIFF OMITTED] TR24JA23.120

    (C) The following example illustrates a calculation of 
mPM:

MPM = 144.0 [micro]g/mol = 144.0 [middot] 10-\6\ 
g/mol
nidexh = 57.692 mol/s
[Delta]t = 1200 s
mPM = 144.0 [middot] 10-\6\ [middot] 57.692 
[middot] 1200
mPM = 9.9692 g

    (4) Additional provisions for diluted exhaust sampling; continuous 
or batch. The following additional provisions apply for sampling 
emissions from diluted exhaust:
    (i) For sampling with a constant dilution ratio, DR, of diluted 
exhaust versus exhaust flow (e.g., secondary dilution for PM sampling), 
calculate m using the following equation:
[GRAPHIC] [TIFF OMITTED] TR24JA23.121

                                Example:

mPMdil = 6.853 g
DR = 6:1
mPM = 6.853 [middot] 6
mPM = 41.118 g

    (ii) For continuous or batch sampling, you may measure background 
emissions in the dilution air. You may then subtract the measured 
background emissions, as described in Sec.  1065.667.
    (5) Mass of NMHC. Compare the corrected mass of NMHC to corrected 
mass of THC. If the corrected mass of NMHC is greater than 0.98 times 
the corrected mass of THC, take the corrected mass of NMHC to be 0.98 
times the corrected mass of THC. If you omit the NMHC calculations as 
described in Sec.  1065.660(b)(1), take the corrected mass of NMHC to be 
0.98 times the corrected mass of THC.
    (6) Mass of NMNEHC. Determine the mass of NMNEHC using one of the 
following methods:
    (i) If the test fuel has less than 0.010 mol/mol of ethane and you 
omit the NMNEHC calculations as described in Sec.  1065.660(c)(1), take 
the corrected mass of NMNEHC to be 0.95 times the corrected mass of 
NMHC.
    (ii) If the test fuel has at least 0.010 mol/mol of ethane and you 
omit the NMNEHC calculations as described in Sec.  1065.660(c)(1), take 
the corrected mass of NMNEHC to be 1.0 times the corrected mass of NMHC.
    (d) Total work over a test interval. To calculate the total work 
from the engine over a test interval, add the total work from all the 
work paths described in Sec.  1065.210 that cross the system boundary 
including electrical energy/work, mechanical shaft work, and fluid 
pumping work. For all work paths, except the engine's primary output 
shaft (crankshaft), the total work for the path over the test interval 
is the integration of the net work flow rate (power) out of the system 
boundary. When energy/work flows into the system boundary, this work 
flow rate signal becomes negative; in this case, include these negative 
work rate values in the integration to calculate total work from that 
work path. Some work paths may result in a negative total work. Include 
negative total work values from any work path in the calculated total 
work from the engine rather than setting the values to zero. The rest of 
this paragraph (d) describes how to calculate total work from the 
engine's primary output shaft over a test interval. Before integrating 
power on the engine's primary output shaft, adjust the speed and torque 
data for the time alignment used in Sec.  1065.514(c). Any advance or 
delay used on the feedback signals for cycle validation must also be 
used for calculating work. Account for work of accessories according

[[Page 220]]

to Sec.  1065.110. Exclude any work during cranking and starting. 
Exclude work during actual motoring operation (negative feedback 
torques), unless the engine was connected to one or more energy storage 
devices. Examples of such energy storage devices include hybrid 
powertrain batteries and hydraulic accumulators, like the ones 
illustrated in Figure 1 of Sec.  1065.210. Exclude any work during 
reference zero-load idle periods (0% speed or idle speed with 0 
N[middot]m reference torque). Note, that there must be two consecutive 
reference zero load idle points to establish a period where the zero-
load exclusion applies. Include work during idle points with simulated 
minimum torque such as Curb Idle Transmissions Torque (CITT) for 
automatic transmissions in ``drive''. The work calculation method 
described in paragraphs (d)(1) though (7) of this section meets the 
requirements of this paragraph (d) using rectangular integration. You 
may use other logic that gives equivalent results. For example, you may 
use a trapezoidal integration method as described in paragraph (d)(8) of 
this section.
    (1) Time align the recorded feedback speed and torque values by the 
amount used in Sec.  1065.514(c).
    (2) Calculate shaft power at each point during the test interval by 
multiplying all the recorded feedback engine speeds by their respective 
feedback torques.
    (3) Adjust (reduce) the shaft power values for accessories according 
to Sec.  1065.110.
    (4) Set all power values during any cranking or starting period to 
zero. See Sec.  1065.525 for more information about engine cranking.
    (5) Set all negative power values to zero, unless the engine was 
connected to one or more energy storage devices. If the engine was 
tested with an energy storage device, leave negative power values 
unaltered.
    (6) Set all power values to zero during idle periods with a 
corresponding reference torque of 0 N [middot] m.
    (7) Integrate the resulting values for power over the test interval. 
Calculate total work as follows:
[GRAPHIC] [TIFF OMITTED] TR24JA23.122

Where:

W = total work from the primary output shaft.
Pi = instantaneous power from the primary output shaft over an interval 
          i.
          [GRAPHIC] [TIFF OMITTED] TR24JA23.123
          
                                Example:

N = 9000
[fnof]n1 = 1800.2 r/min
[fnof]n2 = 1805.8 r/min
T1 = 177.23 N[middot]m
T2 = 175.00 N[middot]m
Crev = 2[middot][pi] rad/r
Ct1 = 60 s/min
Cp = 1000 (N[middot]m[middot]rad/s)/kW
[fnof]record = 5 Hz
Ct2 = 3600 s/hr

[[Page 221]]

[GRAPHIC] [TIFF OMITTED] TR24JA23.124

P1 = 33.41 kW
P2 = 33.09 kW

    Using Eq. 1065.650-5:

[Delta]t = 1/5 = 0.2 s
[GRAPHIC] [TIFF OMITTED] TR24JA23.125

W = 16.875 kW[middot]hr

    (8) You may use a trapezoidal integration method instead of the 
rectangular integration described in this paragraph (d). To do this, you 
must integrate the fraction of work between points where the torque is 
positive. You may assume that speed and torque are linear between data 
points. You may not set negative values to zero before running the 
integration.
    (e) Steady-state mass rate divided by power. To determine steady-
state brake-specific emissions for a test interval as described in 
paragraph (b)(2) of this section, calculate the mean steady-state mass 
rate of the emission, mi, and the mean steady-state power, P as follows:
    (1) To calculate, mi, multiply its mean concentration, x, by its 
corresponding mean molar flow rate, ni. If the result is a molar flow 
rate, convert this quantity to a mass rate by multiplying it by its 
molar mass, M. The result is the mean mass rate of the emission, mi. In 
the case of PM emissions, where the mean PM concentration is already in 
units of mass per mole of exhaust, simply multiply it by the mean molar 
flow rate, ni. The result is the mass rate of PM, mPM. 
Calculate mi using the following equation:
[GRAPHIC] [TIFF OMITTED] TR24JA23.126

    (2) To calculate an engine's mean steady-state total power, P, add 
the mean steady-state power from all the work paths described in Sec.  
1065.210 that cross the system boundary including electrical power, 
mechanical shaft power, and fluid pumping power. For all work paths, 
except the engine's primary output shaft (crankshaft), the mean steady-
state power over the test interval is the integration of the net work 
flow rate (power) out of the system boundary divided by the period of 
the test interval. When power flows into the system boundary, the power/
work flow rate signal becomes negative; in this case, include these 
negative power/work rate values in the integration to calculate the mean 
power from that work path. Some work paths may result in a negative mean 
power. Include negative mean power values from any work path in the mean 
total power from the engine rather than setting these values to zero. 
The rest of this paragraph (e)(2) describes how to calculate the mean 
power from the engine's primary output shaft. Calculate P using Eq. 
1065.650-13, noting that P, fn, and T refer to mean power, 
mean rotational shaft frequency, and mean torque from the primary output 
shaft. Account for the power of simulated accessories according to Sec.  
1065.110 (reducing the mean primary output shaft power or torque by the 
accessory power

[[Page 222]]

or torque). Set the power to zero during actual motoring operation 
(negative feedback torques), unless the engine was connected to one or 
more energy storage devices. Examples of such energy storage devices 
include hybrid powertrain batteries and hydraulic accumulators, like the 
ones denoted ``Acc.'' and ``Batt.'' as illustrated in Figure 1 of Sec.  
1065.210. Set the power to zero for modes with a zero reference load (0 
N[middot]m reference torque or 0 kW reference power). Include power 
during idle modes with simulated minimum torque or power.
[GRAPHIC] [TIFF OMITTED] TR24JA23.127

    (3) Divide emission mass rate by power to calculate a brake-specific 
emission result as described in paragraph (b)(2) of this section.
    (4) The following example shows how to calculate mass of emissions 
using mean mass rate and mean power:

MCO = 28.0101 g/mol
xCO = 12.00 mmol/mol = 0.01200 mol/mol
ni = 1.530 mol/s
fn = 3584.5 r/min = 375.37 rad/s
T = 121.50 N [middot] m
mi = 28.0101 [middot] 0.01200 [middot] 1.530
mi = 0.514 g/s = 1850.4 g/hr
P = 121.5 [middot] 375.37
P = 45607 W
P = 45.607 kW
eCO = 1850.4/45.61
eCO = 40.57 g/(kW [middot] hr)

    (f) Ratio of total mass of emissions to total work. To determine 
brake-specific emissions for a test interval as described in paragraph 
(b)(3) of this section, calculate a value proportional to the total mass 
of each emission. Divide each proportional value by a value that is 
similarly proportional to total work.
    (1) Total mass. To determine a value proportional to the total mass 
of an emission, determine total mass as described in paragraph (c) of 
this section, except substitute for the molar flow rate, n, or the total 
flow, n, with a signal that is linearly proportional to molar flow rate, 
n, or linearly proportional to total flow, n, as follows:
[GRAPHIC] [TIFF OMITTED] TR24JA23.128

    (2) Total work. To calculate a value proportional to total work over 
a test interval, integrate a value that is proportional to power. Use 
information about the brake-specific fuel consumption of your engine, 
efuel, to convert a signal proportional to fuel flow rate to 
a signal proportional to power. To determine a signal proportional to 
fuel flow rate, divide a signal that is proportional to the mass rate of 
carbon products by the fraction of carbon in your fuel, wC. 
You may use a measured wC or you may use default values for a 
given fuel as described in Sec.  1065.655(e). Calculate the mass rate of 
carbon from the amount of carbon and water in the exhaust, which you 
determine with a chemical balance of fuel, DEF, intake air, and exhaust 
as described in Sec.  1065.655. In the chemical balance, you must use 
concentrations from the flow that generated the signal proportional to 
molar flow rate, ni, in paragraph (e)(1) of this section. Calculate a 
value proportional to total work as follows:

[[Page 223]]

[GRAPHIC] [TIFF OMITTED] TR24JA23.129

Where:
[GRAPHIC] [TIFF OMITTED] TR24JA23.130

    (3) Brake-specific emissions. Divide the value proportional to total 
mass by the value proportional to total work to determine brake-specific 
emissions, as described in paragraph (b)(3) of this section.
    (4) Example: The following example shows how to calculate mass of 
emissions using proportional values:

N = 3000
[fnof]record = 5 Hz
efuel = 285 g/(kW[middot]hr)
wfuel = 0.869 g/g
MC = 12.0107 g/mol
nj1 = 3.922 mol/s = 14119.2 mol/hr
xCcombdry1 = 91.634 mmol/mol = 0.091634 mol/mol
xH2Oexh1 = 27.21 mmol/mol = 0.02721 mol/mol
    Using Eq. 1065.650-5,
[Delta]t = 0.2 s
[GRAPHIC] [TIFF OMITTED] TR25OC16.201

W = 5.09 (kW[middot]hr)

    (g) Brake-specific emissions over a duty cycle with multiple test 
intervals. The standard-setting part may specify a duty cycle with 
multiple test intervals, such as with discrete-mode steady-state 
testing. Unless we specify otherwise, calculate composite brake-specific 
emissions over the duty cycle as described in this paragraph (g). If a 
measured mass (or mass rate) is negative, set it to zero for calculating 
composite brake-specific emissions, but leave it unchanged for drift 
validation. In the case of calculating composite brake-specific 
emissions relative to a combined emission standard (such as a 
NOX + NMHC standard), change any negative mass (or mass rate) 
values to zero for a particular pollutant before combining the values 
for the different pollutants.
    (1) Use the following equation to calculate composite brake-specific 
emissions for duty cycles with multiple test intervals all with 
prescribed durations, such as cold-start and hot-start transient cycles:

[[Page 224]]

[GRAPHIC] [TIFF OMITTED] TR24JA23.131

Where:

i = test interval number.
N = number of test intervals.
WF = weighting factor for the test interval as defined in the standard-
          setting part.
m = mass of emissions over the test interval as determined in paragraph 
          (c) of this section.
W = total work from the engine over the test interval as determined in 
          paragraph (d) of this section.

                                Example:

N = 2
WF1 = 0.1428
WF2 = 0.8572
m1 = 70.125 g
m2 = 64.975 g
W1 = 25.783 kW[middot]hr
W2 = 25.783 kW[middot]hr
[GRAPHIC] [TIFF OMITTED] TR24JA23.132

eNOxcomp = 2.548 g/kW[middot]hr

    (2) Calculate composite brake-specific emissions for duty cycles 
with multiple test intervals that allow use of varying duration, such as 
discrete-mode steady-state duty cycles, as follows:
    (i) Use the following equation if you calculate brake-specific 
emissions over test intervals based on total mass and total work as 
described in paragraph (b)(1) of this section:
[GRAPHIC] [TIFF OMITTED] TR24JA23.133

Where:

i = test interval number.
N = number of test intervals.
WF = weighting factor for the test interval as defined in the standard-
          setting part.
m = mass of emissions over the test interval as determined in paragraph 
          (c) of this section.
W = total work from the engine over the test interval as determined in 
          paragraph (d) of this section.
t = duration of the test interval.

                                Example:

N = 2
WF1 = 0.85
WF2 = 0.15
m1 = 1.3753 g
m2 = 0.4135 g
t1 = 120 s
t2 = 200 s
W1 = 2.8375 kW [middot] hr
W2 = 0.0 kW [middot] hr

[[Page 225]]

[GRAPHIC] [TIFF OMITTED] TR24JA23.134

eNOxcomp = 0.5001 g/kW[middot]hr

    (ii) Use the following equation if you calculate brake-specific 
emissions over test intervals based on the ratio of mass rate to power 
as described in paragraph (b)(2) of this section:
[GRAPHIC] [TIFF OMITTED] TR24JA23.135

Where:

i = test interval number.
N = number of test intervals.
WF = weighting factor for the test interval as defined in the standard-
          setting part.
mi = mean steady-state mass rate of emissions over the test interval as 
          determined in paragraph (e) of this section.
p = mean steady-state power over the test interval as described in 
          paragraph (e) of this section.

                                Example:

N = 2
WF1 = 0.85
WF2 = 0.15
mi1 = 2.25842 g/hr
mi2 = 0.063443 g/hr
P1 = 4.5383 kW
P2 = 0.0 kW
[GRAPHIC] [TIFF OMITTED] TR24JA23.136

eNOxcomp = 0.5001 g/kW[middot]hr
    (h) Rounding. Round the final brake-specific emission values to be 
compared to the applicable standard only after all calculations are 
complete (including any drift correction, applicable deterioration 
factors, adjustment factors, and allowances) and the result is in g/(kW 
[middot] hr) or units equivalent to the units of the standard, such as 
g/(hp [middot] hr). See the definition of ``Round'' in Sec.  1065.1001.

[73 FR 37328, June 30, 2008, as amended at 73 FR 59332, Oct. 8, 2008; 75 
FR 23048, Apr. 30, 2010; 76 FR 57457, Sept. 15, 2011;79 FR 23799, Apr. 
28, 2014; 80 FR 9118, Feb. 19, 2015; 81 FR 74180, Oct. 25, 2016; 86 FR 
34560, June 29, 2021; 87 FR 64866, Oct. 26, 2022; 88 FR 4681, Jan. 24, 
2023]



Sec.  1065.655  Chemical balances of fuel, DEF, intake air, and exhaust.

    (a) General. Chemical balances of fuel, intake air, and exhaust may 
be used to calculate flows, the amount of water in their flows, and the 
wet concentration of constituents in their flows. With one flow rate of 
either fuel, intake air, or exhaust, you may use chemical balances to 
determine the flows of the other two. For example, you may use chemical 
balances along with either intake air or fuel flow to determine raw 
exhaust flow. Note that chemical balance calculations allow measured 
values for the flow rate of diesel exhaust fluid for engines with urea-
based selective catalytic reduction.

[[Page 226]]

    (b) Procedures that require chemical balances. We require chemical 
balances when you determine the following:
    (1) A value proportional to total work, W, when you choose to 
determine brake-specific emissions as described in Sec.  1065.650(f).
    (2) Raw exhaust molar flow rate either from measured intake air 
molar flow rate or from fuel mass flow rate as described in paragraph 
(f) of this section.
    (3) Raw exhaust molar flow rate from measured intake air molar flow 
rate and dilute exhaust molar flow rate, as described in paragraph (g) 
of this section.
    (4) The amount of water in a raw or diluted exhaust flow, 
[chi]H2Oexh, when you do not measure the amount of water to 
correct for the amount of water removed by a sampling system. Correct 
for removed water according to Sec.  1065.659.
    (5) The calculated total dilution air flow when you do not measure 
dilution air flow to correct for background emissions as described in 
Sec.  1065.667(c) and (d).
    (c) Chemical balance procedure. The calculations for a chemical 
balance involve a system of equations that require iteration. We 
recommend using a computer to solve this system of equations. You must 
guess the initial values of up to three quantities: the amount of water 
in the measured flow, xH2Oexh, fraction of dilution air in 
diluted exhaust, xdil/exh, and the amount of products on a 
C1 basis per dry mole of dry measured flow, 
xCcombdry. You may use time-weighted mean values of intake 
air humidity and dilution air humidity in the chemical balance; as long 
as your intake air and dilution air humidities remain within tolerances 
of 0.0025 mol/mol of their respective mean values 
over the test interval. For each emission concentration, x, and amount 
of water, xH2Oexh, you must determine their completely dry 
concentrations, xdry and xH2Oexhdry. You must also 
use your fuel mixture's atomic hydrogen-to-carbon ratio, [alpha], 
oxygen-to-carbon ratio, [beta], sulfur-to-carbon ratio, [gamma], and 
nitrogen-to-carbon ratio, [delta]; you may optionally account for diesel 
exhaust fluid (or other fluids injected into the exhaust), if 
applicable. You may calculate [alpha], [beta], [gamma], and [delta] 
based on measured fuel composition or based on measured fuel and diesel 
exhaust fluid (or other fluids injected into the exhaust) composition 
together, as described in paragraph (e) of this section. You may 
alternatively use any combination of default values and measured values 
as described in paragraph (e) of this section. Use the following steps 
to complete a chemical balance:
    (1) Convert your measured concentrations such as, 
xCO2meas, xNOmeas, and xH2Oint, to dry 
concentrations by dividing them by one minus the amount of water present 
during their respective measurements; for example: 
xH2OxCO2meas, xH2OxNOmeas, and xH2Oint. 
If the amount of water present during a ``wet'' measurement is the same 
as the unknown amount of water in the exhaust flow, xH2Oexh, 
iteratively solve for that value in the system of equations. If you 
measure only total NOX and not NO and NO2 
separately, use good engineering judgment to estimate a split in your 
total NOX concentration between NO and NO2 for the 
chemical balances. For example, if you measure emissions from a 
stoichiometric spark-ignition engine, you may assume all NOX 
is NO. For a compression-ignition engine, you may assume that your molar 
concentration of NOX, xNOx, is 75% NO and 25% 
NO2. For NO2 storage aftertreatment systems, you 
may assume xNOx is 25% NO and 75% NO2. Note that 
for calculating the mass of NOX emissions, you must use the 
molar mass of NO2 for the effective molar mass of all 
NOX species, regardless of the actual NO2 fraction 
of NOX.
    (2) Enter the equations in paragraph (c)(4) of this section into a 
computer program to iteratively solve for xH2Oexh, 
xCcombdry, and xdil/exh. Use good engineering 
judgment to guess initial values for xH2Oexh, 
xCcombdry, and xdil/exh. We recommend guessing an 
initial amount of water that is about twice the amount of water in your 
intake or dilution air. We recommend guessing an initial value of 
xCcombdry as the sum of your measured CO2, CO, and 
THC values. We also recommend guessing an initial xdil/exh 
between 0.75 and 0.95, such as 0.8. Iterate values in the system of 
equations until the most recently updated

[[Page 227]]

guesses are all within 1% of their respective most 
recently calculated values.
    (3) Use the following symbols and subscripts in the equations for 
performing the chemical balance calculations in this paragraph (c):

 Table 1 of Sec.   1065.655--Symbols and Subscripts for Chemical Balance
                                Equations
------------------------------------------------------------------------
                                Amount of dilution gas or excess air per
           xdil/exh                         mole of exhaust
------------------------------------------------------------------------
Xdil/exh.....................  amount of dilution gas or excess air per
                                mole of exhaust.
xCcombdry....................  amount of carbon from fuel and any
                                injected fluids in the exhaust per mole
                                of dry exhaust
xH2dry.......................  amount of H2 in exhaust per amount of dry
                                exhaust
KH2Ogas......................  water-gas reaction equilibrium
                                coefficient; you may use 3.5 or
                                calculate your own value using good
                                engineering judgment
xH2Oexhdry...................  amount of H2O in exhaust per dry mole of
                                dry exhaust
xprod/intdry.................  amount of dry stoichiometric products per
                                dry mole of intake air
xdil/exhdry..................  amount of dilution gas and/or excess air
                                per mole of dry exhaust
xint/exhdry..................  amount of intake air required to produce
                                actual combustion products per mole of
                                dry (raw or diluted) exhaust
xraw/exhdry..................  amount of undiluted exhaust, without
                                excess air, per mole of dry (raw or
                                diluted) exhaust
xO2int.......................  amount of intake air O2 per mole of
                                intake air
xCO2intdry...................  amount of intake air CO2 per mole of dry
                                intake air; you may use xCO2intdry = 375
                                [micro]mol/mol, but we recommend
                                measuring the actual concentration in
                                the intake air
xH2Ointdry...................  amount of intake air H2O per mole of dry
                                intake air
xCO2int......................  amount of intake air CO2 per mole of
                                intake air
xCO2dil......................  amount of dilution gas CO2 per mole of
                                dilution gas
xCO2dildry...................  amount of dilution gas CO2 per mole of
                                dry dilution gas; if you use air as
                                diluent, you may use xCO2dildry = 375
                                [micro]mol/mol, but we recommend
                                measuring the actual concentration in
                                the intake air
xH2Odildry...................  amount of dilution gas H2O per mole of
                                dry dilution gas
xH2Odil......................  amount of dilution gas H2O per mole of
                                dilution gas
x[emission]meas..............  amount of measured emission in the sample
                                at the respective gas analyzer
x[emission]dry...............  amount of emission per dry mole of dry
                                sample
xH2O[emission]meas...........  amount of H2O in sample at emission-
                                detection location; measure or estimate
                                these values according to Sec.
                                1065.145(e)(2)
xH2Oint......................  amount of H2O in the intake air, based on
                                a humidity measurement of intake air
[alpha]......................  atomic hydrogen-to-carbon ratio of the
                                fuel (or mixture of test fuels) and any
                                injected fluids
[beta].......................  atomic oxygen-to-carbon ratio of the fuel
                                (or mixture of test fuels) and any
                                injected fluids
[gamma]......................  atomic sulfur-to-carbon ratio of the fuel
                                (or mixture of test fuels) and any
                                injected fluids
[delta]......................  atomic nitrogen-to-carbon ratio of the
                                fuel (or mixture of test fuels) and any
                                injected fluids
------------------------------------------------------------------------


    (4) Use the following equations to iteratively solve for 
xdil/exh, xH2Oexh, and xCcombdry:
[GRAPHIC] [TIFF OMITTED] TR30AP10.051

[GRAPHIC] [TIFF OMITTED] TR30AP10.052

[GRAPHIC] [TIFF OMITTED] TR30AP10.053

[GRAPHIC] [TIFF OMITTED] TR30AP10.054

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[[Page 228]]


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[GRAPHIC] [TIFF OMITTED] TR30AP10.066

[GRAPHIC] [TIFF OMITTED] TR30AP10.067

[GRAPHIC] [TIFF OMITTED] TR30AP10.068

    (5) The following example is a solution for xdil/exh,x, 
xH2Oexh, and xCcombdry using the equations in 
paragraph (c)(4) of this section:

[[Page 229]]

[GRAPHIC] [TIFF OMITTED] TR15SE11.050

[GRAPHIC] [TIFF OMITTED] TR15SE11.051


[[Page 230]]


[GRAPHIC] [TIFF OMITTED] TR15SE11.052

a = 1.8
b = 0.05
g = 0.0003
d = 0.0001

    (d) Carbon mass fraction of fuel. Determine carbon mass fraction of 
fuel, wC, based on the fuel properties as determined in 
paragraph (e) of this section,

[[Page 231]]

optionally accounting for diesel exhaust fluid's contribution to 
[alpha], [beta], [gamma], and [delta], or other fluids injected into the 
exhaust, if applicable (for example, the engine is equipped with an 
emission control system that utilizes DEF). Calculate wC 
using the following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.204

Where:

wC = carbon mass fraction of the fuel (or mixture of test 
          fuels) and any injected fluids.
MC = molar mass of carbon.
a = atomic hydrogen-to-carbon ratio of the fuel (or mixture of test 
          fuels) and any injected fluids.
MH = molar mass of hydrogen.
b = atomic oxygen-to-carbon ratio of the fuel (or mixture of test fuels) 
          and any injected fluids.
MO = molar mass of oxygen.
g = atomic sulfur-to-carbon ratio of the fuel (or mixture of test fuels) 
          and any injected fluids.
MS = molar mass of sulfur.
d = atomic nitrogen-to-carbon ratio of the fuel (or mixture of test 
          fuels) and any injected fluids.
MN = molar mass of nitrogen.

    Example: 
a = 1.8
b = 0.05
g = 0.0003
d = 0.0001
MC = 12.0107
MH = 1.00794
MO = 15.9994
MS = 32.065
MN = 14.0067
[GRAPHIC] [TIFF OMITTED] TR25OC16.205

wC = 0.8206

    (e) Fuel and diesel exhaust fluid composition. Determine fuel and 
diesel exhaust fluid composition represented by [alpha], [beta], 
[gamma], and [delta] as described in this paragraph (e). When using 
measured fuel or diesel exhaust fluid properties, you must determine 
values for [alpha] and [beta] in all cases. If you determine 
compositions based on measured values and the default value listed in 
Table 2 of this section is zero, you may set [gamma] and [delta] to 
zero; otherwise determine [gamma] and [delta] (along with [alpha] and 
[beta]) based on measured values. Determine elemental mass fractions and 
values for [alpha], [beta], [gamma], and [delta] as follows:
    (1) For liquid fuels, use the default values for [alpha], [beta], 
[gamma], and [delta] in Table 2 of this section or determine mass 
fractions of liquid fuels for calculation of [alpha], [beta], [gamma], 
and [delta] as follows:
    (i) Determine the carbon and hydrogen mass fractions according to 
ASTM D5291 (incorporated by reference in Sec.  1065.1010). When using 
ASTM D5291 to determine carbon and hydrogen mass fractions of gasoline 
(with or without blended ethanol), use good engineering judgment to 
adapt the method as appropriate. This may include consulting with the 
instrument manufacturer on how to test high-volatility fuels. Allow the 
weight of volatile fuel samples to stabilize for 20 minutes before 
starting the analysis; if the weight still drifts after 20 minutes, 
prepare a new sample). Retest the sample if the carbon, hydrogen, 
oxygen, sulfur, and nitrogen mass fractions do not add up to a total 
mass of 100 0.5%; you may assume oxygen has a zero 
mass contribution for this specification for diesel fuel and neat (E0) 
gasoline. You may also assume that sulfur and nitrogen have a

[[Page 232]]

zero mass contribution for this specification for all fuels except 
residual fuel blends.
    (ii) Determine oxygen mass fraction of gasoline (with or without 
blended ethanol) according to ASTM D5599 (incorporated by reference in 
Sec.  1065.1010). For all other liquid fuels, determine the oxygen mass 
fraction using good engineering judgment.
    (iii) Determine the nitrogen mass fraction according to ASTM D4629 
or ASTM D5762 (incorporated by reference in Sec.  1065.1010) for all 
liquid fuels. Select the correct method based on the expected nitrogen 
content.
    (iv) Determine the sulfur mass fraction according to subpart H of 
this part.
    (2) For gaseous fuels and diesel exhaust fluid, use the default 
values for [alpha], [beta], [gamma], and [delta] in Table 2 of this 
section, or use good engineering judgment to determine those values 
based on measurement.
    (3) For nonconstant fuel mixtures, you must account for the varying 
proportions of the different fuels. This paragraph (e)(3) generally 
applies for dual-fuel and flexible-fuel engines, but it also applies if 
diesel exhaust fluid is injected in a way that is not strictly 
proportional to fuel flow. Account for these varying concentrations 
either with a batch measurement that provides averaged values to 
represent the test interval, or by analyzing data from continuous mass 
rate measurements. Application of average values from a batch 
measurement generally applies to situations where one fluid is a minor 
component of the total fuel mixture, for example dual-fuel and flexible-
fuel engines with diesel pilot injection, where the diesel pilot fuel 
mass is less than 5% of the total fuel mass and diesel exhaust fluid 
injection; consistent with good engineering judgment.
    (4) Calculate [alpha], [beta], [gamma], and [delta] using the 
following equations:
[GRAPHIC] [TIFF OMITTED] TR24JA23.137

Where:

N = total number of fuels and injected fluids over the duty cycle.
j = an indexing variable that represents one fuel or injected fluid, 
          starting with j = 1.
mj = the mass flow rate of the fuel or any injected fluid j. For 
          applications using a single fuel and no DEF fluid, set this 
          value to 1. For batch measurements, divide the total mass of 
          fuel over the test interval duration to determine a mass rate.
wHj = hydrogen mass fraction of fuel or any injected fluid j.

[[Page 233]]

wCj = carbon mass fraction of fuel or any injected fluid j.
wOj = oxygen mass fraction of fuel or any injected fluid j.
wSj = sulfur mass fraction of fuel or any injected fluid j.
wNj = nitrogen mass fraction of fuel or any injected fluid j.

                                Example:

N = 1
j = 1
m1 = 1
wH1 = 0.1239
wC1 = 0.8206
    wO1 = 0.0547
    wS1 = 0.00066
    wN1 = 0.000095
    MC = 12.0107 g/mol
    MH = 1.00794 g/mol
    MO = 15.9994 g/mol
    MS = 32.065 g/mol
    MN = 14.0067
    [GRAPHIC] [TIFF OMITTED] TR24JA23.138
    
[alpha] = 1.799
[beta] = 0.05004
[gamma] = 0.0003012
[delta] = 0.0001003

    (5) Table 2 follows:

[[Page 234]]

[GRAPHIC] [TIFF OMITTED] TR29JN21.251

    (f) Calculated raw exhaust molar flow rate from measured intake air 
molar flow rate or fuel mass flow rate. You may calculate the raw 
exhaust molar flow rate from which you sampled emissions, 
nexh, based on the measured intake air molar flow rate, 
nint, or the measured fuel mass flow rate, mfuel, 
and the values calculated using the chemical balance in paragraph (c) of 
this section. The chemical balance must be based on raw exhaust gas 
concentrations. Solve for the chemical balance in paragraph (c) of this 
section at the same frequency that you update and record or 
nint or mfuel. For laboratory tests, calculating 
raw exhaust molar flow rate using measured fuel mass flow rate is valid 
only for steady-state testing. See Sec.  1065.915(d)(5)(iv) for 
application to field testing.
    (1) Crankcase flow rate. If engines are not subject to crankcase 
controls under the standard-setting part, you may calculate raw exhaust 
flow based on nint or mfuel using one of the 
following:
    (i) You may measure flow rate through the crankcase vent and 
subtract it from the calculated exhaust flow.
    (ii) You may estimate flow rate through the crankcase vent by 
engineering analysis as long as the uncertainty in your calculation does 
not adversely affect your ability to show that your engines comply with 
applicable emission standards.
    (iii) You may assume your crankcase vent flow rate is zero.
    (2) Intake air molar flow rate calculation. Calculate 
nexh based on nint using the following equation:

[[Page 235]]

[GRAPHIC] [TIFF OMITTED] TR28AP14.049

Where:

nexh = raw exhaust molar flow rate from which you measured 
          emissions.
nint = intake air molar flow rate including humidity in 
          intake air.

    Example: 
nint = 3.780 mol/s
xint/exhdry = 0.69021 mol/mol
xraw/exhdry = 1.10764 mol/mol
xH20exhdry = 107.64 mmol/mol = 0.10764 mol/mol
[GRAPHIC] [TIFF OMITTED] TR28AP14.050

    (3) Fluid mass flow rate calculation. This calculation may be used 
only for steady-state laboratory testing. You may not use this 
calculation if the standard-setting part requires carbon balance error 
verification as described in Sec.  1065.543. See Sec.  
1065.915(d)(5)(iv) for application to field testing. Calculate 
nexh based on mj using the following equation:
[GRAPHIC] [TIFF OMITTED] TR24JA23.139

Where:

nexh = raw exhaust molar flow rate from which you measured 
          emissions.
j = an indexing variable that represents one fuel or injected fluid, 
          starting with j = 1.
N = total number of fuels and injected fluids over the duty cycle.
mj = the mass flow rate of the fuel or any injected fluid j.
wCj = carbon mass fraction of the fuel and any injected fluid 
          j.

                                Example:

N = 1
j = 1
m1 = 7.559 g/s
wC1 = 0.869 g/g
MC = 12.0107 g/mol
xCcombdry1 = 99.87 mmol/mol = 0.09987 mol/mol
xH20exhdry1 = 107.64 mmol/mol = 0.10764 mol/mol
[GRAPHIC] [TIFF OMITTED] TR24JA23.140


[[Page 236]]


nexh = 6.066 mol/s

    (g) Calculated raw exhaust molar flow rate from measured intake air 
molar flow rate, dilute exhaust molar flow rate, and dilute chemical 
balance. You may calculate the raw exhaust molar flow rate, 
nexh, based on the measured intake air molar flow rate, 
nint, the measured dilute exhaust molar flow rate, 
ndexh, and the values calculated using the chemical balance 
in paragraph (c) of this section. Note that the chemical balance must be 
based on dilute exhaust gas concentrations. For continuous-flow 
calculations, solve for the chemical balance in paragraph (c) of this 
section at the same frequency that you update and record nint 
and ndexh. This calculated nexh may be used for 
the PM dilution ratio verification in Sec.  1065.546; the calculation of 
dilution air molar flow rate in the background correction in Sec.  
1065.667; and the calculation of mass of emissions in Sec.  1065.650(c) 
for species that are measured in the raw exhaust.
    (1) Crankcase flow rate. If engines are not subject to crankcase 
controls under the standard-setting part, calculate raw exhaust flow as 
described in paragraph (e)(1) of this section.
    (2) Dilute exhaust and intake air molar flow rate calculation. 
Calculate nexh as follows:
[GRAPHIC] [TIFF OMITTED] TR28AP14.052

    Example: 
nint = 7.930 mol/s
xraw/exhdry = 0.1544 mol/mol
xint/exhdry = 0.1451 mol/mol
xH20/exh = 32.46 mmol/mol = 0.03246 mol/mol
ndexh = 49.02 mol/s
nexh = (0.1544 - 0.1451) [middot] (1 - 0.03246) [middot] 
          49.02 + 7.930 = 0.4411 + 7.930 = 8.371 mol/s

[73 FR 37331, June 30, 2008, as amended at 73 FR 59334, Oct. 8, 2008; 75 
FR 23051, Apr. 30, 2010; 76 FR 57458, Sept. 15, 2011; 79 FR 23799, Apr. 
28, 2014; 81 FR 74182, Oct. 25, 2016; 86 FR 34563, June 29, 2021; 87 FR 
64866, Oct. 26, 2022; 88 FR 4684, Jan. 24, 2023]



Sec.  1065.659  Removed water correction.

    (a) If you remove water upstream of a concentration measurement, x, 
correct for the removed water. Perform this correction based on the 
amount of water at the concentration measurement, 
xH2O[emission]meas, and at the flow meter, 
xH2Oexh, whose flow is used to determine the mass emission 
rate or total mass over a test interval. For continuous analyzers 
downstream of a sample dryer for transient and ramped-modal cycles, you 
must apply this correction on a continuous basis over the test interval, 
even if you use one of the options in Sec.  1065.145(e)(2) that results 
in a constant value for xH2O[emission]meas because 
xH2Oexh varies over the test interval. For batch analyzers, 
determine the flow-weighted average based on the continuous 
xH2Oexh values determined as described in paragraph (c) of 
this section. For batch analyzers, you may determine the flow-weighted 
average xH2Oexh based on a single value of xH2Oexh 
determined as described in paragraphs (c)(2) and (3) of this section, 
using flow-weighted average or batch concentration inputs.
    (b) Determine the amount of water remaining downstream of a sample 
dryer and at the concentration measurement using one of the methods 
described in Sec.  1065.145(e)(2). If you use a sample dryer upstream of 
an analyzer and if the calculated amount of water remaining downstream 
of the sample dryer and at the concentration measurement, 
xH2O[emission]meas, is higher than the amount of water at the 
flow meter, xH2Oexh, set xH2O[emission]meas equal 
to xH2Oexh. If you use a sample dryer upstream of storage 
media, you must be able to demonstrate that the sample dryer is removing 
water continuously (i.e., xH2Oexh is higher than 
xH2O[emission]meas throughout the test interval).
    (c) For a concentration measurement where you did not remove water, 
you may set xH2O[emission]meas equal to xH2Oexh.

[[Page 237]]

You may determine the amount of water at the flow meter, 
xH2Oexh, using any of the following methods:
    (1) Measure the dewpoint and absolute pressure and calculate the 
amount of water as described in Sec.  1065.645.
    (2) If the measurement comes from raw exhaust, you may determine the 
amount of water based on intake-air humidity, plus a chemical balance of 
fuel, DEF, intake air, and exhaust as described in Sec.  1065.655.
    (3) If the measurement comes from diluted exhaust, you may determine 
the amount of water based on intake-air humidity, dilution air humidity, 
and a chemical balance of fuel, DEF, intake air, and exhaust as 
described in Sec.  1065.655.
    (d) Perform a removed water correction to the concentration 
measurement using the following equation:
[GRAPHIC] [TIFF OMITTED] TR28AP14.053


[73 FR 37335, June 30, 2008, as amended at 76 FR 57462, Sept. 15, 2011; 
79 FR 23804, Apr. 28, 2014; 86 FR 34566, June 29, 2021]



Sec.  1065.660  THC, NMHC, NMNEHC, CH4, and C2H6 determination.

    (a) THC determination and initial THC/CH4 contamination 
corrections. (1) If we require you to determine THC emissions, calculate 
xTHC[THC-FID]cor using the initial THC contamination 
concentration xTHC[THC-FID]init from Sec.  1065.520 as 
follows:
[GRAPHIC] [TIFF OMITTED] TR15SE11.058


[[Page 238]]


    Example: 
xTHCuncor = 150.3 [micro]mol/mol
xTHCinit = 1.1 [micro]mol/mol
xTHCcor = 150.3--1.1
xTHCcor = 149.2 [micro]mol/mol

    (2) For the NMHC determination described in paragraph (b) of this 
section, correct xTHC[THC-FID] for initial THC contamination 
using Eq. 1065.660-1. You may correct xTHC[NMC-FID] for 
initial contamination of the CH4 sample train using Eq. 
1065.660-1, substituting in CH4 concentrations for THC.
    (3) For the NMNEHC determination described in paragraph (c) of this 
section, correct xTHC[THC-FID] for initial THC contamination 
using Eq. 1065.660-1. You may correct xTHC[NMC-FID] for 
initial contamination of the CH4 sample train using Eq. 
1065.660-1, substituting in CH4 concentrations for THC.
    (4) For the CH4 determination described in paragraph (d) 
of this section, you may correct xTHC[NMC-FID] for initial 
THC contamination of the CH4 sample train using Eq. 1065.660-
1, substituting in CH4 concentrations for THC.
    (5) You may calculate THC as the sum of NMHC and CH4 if 
you determine CH4 with an FTIR as described in paragraph 
(d)(2) of this section and NMHC with an FTIR using the additive method 
from paragraph (b)(4) of this section.
    (6) You may calculate THC as the sum of NMNEHC, 
C2H6, and CH4 if you determine 
CH4 with an FTIR as described in paragraph (d)(2) of this 
section, C2H6 with an FTIR as described in 
paragraph (e) of this section, and NMNEHC with an FTIR using the 
additive method from paragraph (c)(3) of this section.
    (b) NMHC determination. Use one of the following to determine NMHC 
concentration, xNMHC:
    (1) If you do not measure CH4, you may omit the 
calculation of NMHC concentrations and calculate the mass of NMHC as 
described in Sec.  1065.650(c)(5).
    (2) For nonmethane cutters, calculate [chi]NMHC using the 
nonmethane cutter's methane penetration fraction, 
PFCH4[NMC-FID], and the ethane response factor penetration 
fraction, RFPFC2H6[NMC-FID], from Sec.  1065.365, the THC 
FID's methane response factor, RFCH4[THC-FID], from Sec.  
1065.360, the initial THC contamination and dry-to-wet corrected THC 
concentration, [chi]THC[THC-FID]cor, as determined in 
paragraph (a) of this section, and the dry-to-wet corrected methane 
concentration, [chi]THC[NMC-FID]cor, optionally corrected for 
initial THC contamination as determined in paragraph (a) of this 
section.
    (i) If you need to account for penetration fractions determined as a 
function of molar water concentration, use Eq. 1065.660-4. Otherwise, 
use the following equation for penetration fractions determined using an 
NMC configuration as outlined in Sec.  1065.365(d):
[GRAPHIC] [TIFF OMITTED] TR15SE11.059

Where:

xNMHC = concentration of NMHC.
xTHC[THC-FID]cor = concentration of THC, initial THC 
          contamination and dry-to-wet corrected, as measured by the THC 
          FID during sampling while bypassing the NMC.
xTHC[NMC-FID]cor = concentration of THC, initial THC 
          contamination (optional) and dry-to-wet corrected, as measured 
          by the NMC FID during sampling through the NMC.
RFCH4[THC-FID] = response factor of THC FID to 
          CH4, according to Sec.  1065.360(d).
RFPFC2H6[NMC-FID] = nonmethane cutter combined ethane 
          response factor and penetration fraction, according to Sec.  
          1065.365(d).

    Example: 
xTHC[THC-FID]cor = 150.3 [micro]mol/mol
xTHC[NMC-FID]cor = 20.5 [micro]mol/mol
RFPFC2H6[NMC-FID] = 0.019
RFCH4[THC-FID] = 1.05

[[Page 239]]

[GRAPHIC] [TIFF OMITTED] TR15SE11.060

xNMHC = 131.4 [micro]mol/mol

    (ii) Use the following equation for penetration fractions determined 
using an NMC configuration as outlined in Sec.  1065.365(e):
[GRAPHIC] [TIFF OMITTED] TR15SE11.061

Where:

xNMHC = concentration of NMHC.
xTHC[THC-FID]cor = concentration of THC, initial THC 
          contamination and dry-to-wet corrected, as measured by the THC 
          FID during sampling while bypassing the NMC.
PFCH4[NMC-FID] = nonmethane cutter CH4 penetration 
          fraction, according to Sec.  1065.365(e).
xTHC[NMC-FID]cor = concentration of THC, initial THC 
          contamination (optional) and dry-to-wet corrected, as measured 
          by the THC FID during sampling through the NMC.
PFC2H6[NMC-FID] = nonmethane cutter ethane penetration 
          fraction, according to Sec.  1065.365(e).

    Example: 
xTHC[THC-FID]cor = 150.3 [micro]mol/mol
PFCH4[NMC-FID] = 0.990
xTHC[NMC-FID]cor = 20.5 [micro]mol/mol
PFC2H6[NMC-FID] = 0.020
[GRAPHIC] [TIFF OMITTED] TR15SE11.062

xNMHC = 132.3 [micro]mol/mol

    (iii) Use the following equation for penetration fractions 
determined using an NMC configuration as outlined in Sec.  1065.365(f) 
or for penetration fractions determined as a function of molar water 
concentration using an NMC configuration as outlined in Sec.  
1065.365(d):
[GRAPHIC] [TIFF OMITTED] TR15SE11.063

Where:

xNMHC = concentration of NMHC.
xTHC[THC-FID]cor = concentration of THC, initial THC 
          contamination and dry-to-wet corrected, as measured by the THC 
          FID during sampling while bypassing the NMC.
PFCH4[NMC-FID] = nonmethane cutter CH4 penetration 
          fraction, according to Sec.  1065.365(f).
xTHC[NMC-FID]cor = concentration of THC, initial THC 
          contamination (optional) and dry-to-wet corrected, as measured 
          by the

[[Page 240]]

          THC FID during sampling through the NMC.
RFPFC2H6[NMC-FID] = nonmethane cutter CH4 combined 
          ethane response factor and penetration fraction, according to 
          Sec.  1065.365(f).
RFCH4[THC-FID] = response factor of THC FID to 
          CH4, according to Sec.  1065.360(d).

    Example: 
xTHC[THC-FID]cor = 150.3 [micro]mol/mol
PFCH4[NMC-FID] = 0.990
xTHC[NMC-FID]cor = 20.5 [micro]mol/mol
RFPFC2H6[NMC-FID] = 0.019
RFCH4[THC-FID] = 0.980
[GRAPHIC] [TIFF OMITTED] TR15SE11.067

xNMHC = 132.5 [micro]mol/mol

    (3) For a GC-FID or FTIR, calculate [chi]NMHC using the 
THC analyzer's methane response factor, RFCH4[THC-FID], from 
Sec.  1065.360, and the initial THC contamination and dry-to-wet 
corrected THC concentration, [chi]THC[THC-FID]cor, as 
determined in paragraph (a) of this section as follows:
[GRAPHIC] [TIFF OMITTED] TR25OC16.213

Where:

xNMHC = concentration of NMHC.
xTHC[THC-FID]cor = concentration of THC, initial THC 
          contamination and dry-to-wet corrected, as measured by the THC 
          FID.
RFCH4[THC-FID] = response factor of THC-FID to 
          CH4.
xCH4 = concentration of CH4, dry-to-wet corrected, 
          as measured by the GC-FID or FTIR.

    Example: 

xTHC[THC-FID]cor = 145.6 [micro]mol/mol
RFCH4[THC-FID] = 0.970
xCH4 = 18.9 [micro]mol/mol
xNMHC = 145.6-0.970 [middot] 18.9
xNMHC = 127.3 [micro]mol/mol

    (4) For an FTIR, calculate [chi]NMHC by summing the 
hydrocarbon species listed in Sec.  1065.266(c) as follows:
[GRAPHIC] [TIFF OMITTED] TR29JN21.254

Where:

[chi]NMHC = concentration of NMHC.
[chi]HCi = the C1-equivalent concentration of 
          hydrocarbon species i as measured by the FTIR, not corrected 
          for initial contamination.
[chi]HCi-init = the C1-equivalent concentration of 
          the initial system contamination (optional) of hydrocarbon 
          species i, dry-to-wet corrected, as measured by the FTIR.
    Example: 
[chi]C2H6 = 4.9 [micro]mol/mol
[chi]C2H4 = 0.9 [micro]mol/mol
[chi]C2H2 = 0.8 [micro]mol/mol
[chi]C3H8 = 0.4 [micro]mol/mol
[chi]C3H6 = 0.5 [micro]mol/mol
[chi]C4H10 = 0.3 [micro]mol/mol
[chi]CH2O = 0.8 [micro]mol/mol
[chi]C2H4O = 0.3 [micro]mol/mol
[chi]CH2O2 = 0.1 [micro]mol/mol
[chi]CH4O = 0.1 [micro]mol/mol

[[Page 241]]

[chi]NMHC = 4.9 + 0.9 + 0.8 + 0.4 + 0.5 + 0.3 + 0.8 + 0.3 + 
          0.1 + 0.1
[chi]NMHC = 9.1 [micro]mol/mol

    (c) NMNEHC determination. Use one of the following methods to 
determine NMNEHC concentration, xNMNEHC:
    (1) Calculate xNMNEHC based on the test fuel's ethane 
content as follows:
    (i) If the content of your test fuel contains less than 0.010 mol/
mol of ethane, you may omit the calculation of NMNEHC concentration and 
calculate the mass of NMNEHC as described in Sec.  1065.650(c)(6)(i).
    (ii) If the content of your fuel test contains at least 0.010 mol/
mol of ethane, you may omit the calculation of NMNEHC concentration and 
calculate the mass of NMNEHC as described in Sec.  1065.650(c)(6)(ii).
    (2) For a GC-FID, NMC FID, or FTIR, calculate [chi]NMNEHC 
using the THC analyzer's methane response factor, 
RFCH4[THC-FID], and ethane response factor, 
RFC2H6[THC-FID], from Sec.  1065.360, the initial 
contamination and dry-to-wet corrected THC concentration, 
[chi]THC[THC-FID]cor, as determined in paragraph (a) of this 
section, the dry-to-wet corrected methane concentration, 
[chi]CH4, as determined in paragraph (d) of this section, and 
the dry-to-wet corrected ethane concentration, [chi]C2H6, as 
determined in paragraph (e) of this section as follows:
[GRAPHIC] [TIFF OMITTED] TR29JN21.255

Where:

[chi]NMNEHC = concentration of NMNEHC.
[chi]THC[THC-FID]cor = concentration of THC, initial THC 
          contamination and dry-to-wet corrected, as measured by the THC 
          FID.
RFCH4[THC-FID] = response factor of THC-FID to 
          CH4.
[chi]CH4 = concentration of CH4, dry-to-wet 
          corrected, as measured by the GC-FID, NMC FID, or FTIR.
RFC2H6[THC-FID] = response factor of THC-FID to 
          C2H6.
[chi]C2H6 = the C1-equivalent concentration of 
          C2H6, dry-to-wet corrected, as measured 
          by the GC-FID or FTIR.
    Example: 
[chi]THC[THC-FID]cor = 145.6 [micro]mol/mol
RFCH4[THC-FID] = 0.970
[chi]CH4 = 18.9 [micro]mol/mol
RFC2H6[THC-FID] = 1.02
[chi]C2H6 = 10.6 [micro]mol/mol
[chi]NMNEHC = 145.6-0.970 [middot] 18.9-1.02 [middot] 10.6
[chi]NMNEHC = 116.5 [micro]mol/mol

    (3) For an FTIR, calculate xNMNEHC by summing the 
hydrocarbon species listed in Sec.  1065.266(c) as follows:
[GRAPHIC] [TIFF OMITTED] TR25OC16.216

Where:

xNMNEHC = concentration of NMNEHC.
xHCi = the C1-equivalent concentration of 
          hydrocarbon species i as measured by the FTIR, not corrected 
          for initial contamination.
xHCi-init = the C1-equivalent concentration of the 
          initial system contamination (optional) of hydrocarbon species 
          i, dry-to-wet corrected, as measured by the FTIR.
    Example: 
xC2H4 = 0.9 [micro]mol/mol
xC2H2 = 0.8 [micro]mol/mol
xC3H8 = 0.4 [micro]mol/mol

[[Page 242]]

xC3H6 = 0.5 [micro]mol/mol
xC4H10 = 0.3 [micro]mol/mol
xCH2O = 0.8 [micro]mol/mol
xC2H4O = 0.3 [micro]mol/mol
xC2H2O2 = 0.1 [micro]mol/mol
xCH4O = 0.1 [micro]mol/mol
xNMNEHC = 0.9 + 0.8 + 0.4 + 0.5 + 0.3 + 0.8 + 0.3 + 0.1 + 0.1
xNMNEHC = 4.2 [micro]mol/mol

    (d) CH4 determination. Use one of the following methods to determine 
methane concentration, [chi]CH4:
    (1) For nonmethane cutters, calculate [chi]CH4 using the 
nonmethane cutter's methane penetration fraction, 
PFCH4[NMC-FID], and the ethane response factor penetration 
fraction, RFPFC2H6[NMC-FID, from Sec.  1065.365, the THC 
FID's methane response factor, RFCH4[THC-FID], from Sec.  
1065.360, the initial THC contamination and dry-to-wet corrected THC 
concentration, [chi]THC[THC-FID]cor, as determined in 
paragraph (a) of this section, and the dry-to-wet corrected methane 
concentration, [chi]THC[NMC-FID]cor, optionally corrected for 
initial THC contamination as determined in paragraph (a) of this 
section.
    (i) If you need to account for penetration fractions determined as a 
function of molar water concentration, use Eq. 1065.660-11. Otherwise, 
use the following equation for penetration fractions determined using an 
NMC configuration as outlined in Sec.  1065.365(d):
[GRAPHIC] [TIFF OMITTED] TR25OC16.217

Where:

xCH4 = concentration of CH4.
xTHC[NMC-FID]cor = concentration of THC, initial THC 
          contamination (optional) and dry-to-wet corrected, as measured 
          by the NMC FID during sampling through the NMC.
xTHC[THC-FID]cor = concentration of THC, initial THC 
          contamination and dry-to-wet corrected, as measured by the THC 
          FID during sampling while bypassing the NMC.
RFPFC2H6[NMC-FID] = the combined ethane response factor and 
          penetration fraction of the nonmethane cutter, according to 
          Sec.  1065.365(d).
RFCH4[THC-FID] = response factor of THC FID to 
          CH4, according to Sec.  1065.360(d).

    Example: 
xTHC[NMC-FID]cor = 10.4 [micro]mol/mol
xTHC[THC-FID]cor = 150.3 [micro]mol/mol
RFPFC2H6[NMC-FID] = 0.019
RFCH4[THC-FID] = 1.05
[GRAPHIC] [TIFF OMITTED] TR25OC16.218

xCH4 = 7.69 [micro]mol/mol

    (ii) Use the following equation for penetration fractions determined 
using an NMC configuration as outlined in Sec.  1065.365(e):

[[Page 243]]

[GRAPHIC] [TIFF OMITTED] TR25OC16.219

Where:

xCH4 = concentration of CH4.
xTHC[NMC-FID]cor = concentration of THC, initial THC 
          contamination (optional) and dry-to-wet corrected, as measured 
          by the NMC FID during sampling through the NMC.
xTHC[THC-FID]cor = concentration of THC, initial THC 
          contamination and dry-to-wet corrected, as measured by the THC 
          FID during sampling while bypassing the NMC.
PFC2H6[NMC-FID] = nonmethane cutter ethane penetration 
          fraction, according to Sec.  1065.365(e).
RFCH4[THC-FID] = response factor of THC FID to 
          CH4, according to Sec.  1065.360(d).
PFCH4[NMC-FID] = nonmethane cutter CH4 penetration 
          fraction, according to Sec.  1065.365(e).

    Example: 
xTHC[NMC-FID]cor = 10.4 [micro]mol/mol
xTHC[THC-FID]cor = 150.3 [micro]mol/mol
PFC2H6[NMC-FID] = 0.020
RFCH4[THC-FID] = 1.05
PFCH4[NMC-FID] = 0.990
[GRAPHIC] [TIFF OMITTED] TR25OC16.220

xCH4 = 7.25 [micro]mol/mol

    (iii) Use the following equation for penetration fractions 
determined using an NMC configuration as outlined in Sec.  1065.365(f) 
or for penetration fractions determined as a function of molar water 
concentration using an NMC configuration as outlined in Sec.  
1065.365(d):
[GRAPHIC] [TIFF OMITTED] TR25OC16.221

Where:

xCH4 = concentration of CH4.
xTHC[NMC-FID]cor = concentration of THC, initial THC 
          contamination (optional) and dry-to-wet corrected, as measured 
          by the NMC FID during sampling through the NMC.
xTHC[THC-FID]cor = concentration of THC, initial THC 
          contamination and dry-to-wet corrected, as measured by the THC 
          FID during sampling while bypassing the NMC.
RFPFC2H6[NMC-FID] = the combined ethane response factor and 
          penetration fraction of the nonmethane cutter, according to 
          Sec.  1065.365(f).
PFCH4[NMC-FID] = nonmethane cutter CH4 penetration 
          fraction, according to Sec.  1065.365(f).
RFCH4[THC-FID] = response factor of THC FID to 
          CH4, according to Sec.  1065.360(d).

    Example: 
xTHC[NMC-FID]cor = 10.4 [micro]mol/mol
xTHC[THC-FID]cor = 150.3 [micro]mol/mol
RFPFC2H6[NMC-FID] = 0.019
PFCH4[NMC-FID] = 0.990
RFCH4[THC-FID] = 1.05

[[Page 244]]

[GRAPHIC] [TIFF OMITTED] TR25OC16.222

xCH4 = 7.78 [micro]mol/mol

    (2) For a GC-FID or FTIR, [chi]CH4 is the actual dry-to-
wet corrected methane concentration as measured by the analyzer.
    (e) C2H6 determination. For a GC-FID or FTIR, [chi]C2H6 
is the C1-equivalent, dry-to-wet corrected ethane 
concentration as measured by the analyzer.

[76 FR 57462, Sept. 15, 2011, as amended at 81 FR 74184, Oct. 25, 2016; 
86 FR 34566, June 29, 2021; 88 FR 4686, Jan. 24, 2023]



Sec.  1065.665  THCE and NMHCE determination.

    (a) If you measured an oxygenated hydrocarbon's mass concentration, 
first calculate its molar concentration in the exhaust sample stream 
from which the sample was taken (raw or diluted exhaust), and convert 
this into a C1-equivalent molar concentration. Add these 
C1-equivalent molar concentrations to the molar concentration 
of non-oxygenated total hydrocarbon (NOTHC). The result is the molar 
concentration of total hydrocarbon equivalent (THCE). Calculate THCE 
concentration using the following equations, noting that Eq. 1065.665-3 
is required only if you need to convert your oxygenated hydrocarbon 
(OHC) concentration from mass to moles:
[GRAPHIC] [TIFF OMITTED] TR29JN21.256

[GRAPHIC] [TIFF OMITTED] TR29JN21.257

[GRAPHIC] [TIFF OMITTED] TR29JN21.258

Where:

[chi]THCE = the sum of the C1-equivalent 
          concentrations of non-oxygenated hydrocarbon, alcohols, and 
          aldehydes.
[chi]NOTHC = the sum of the C1-equivalent 
          concentrations of NOTHC.
[chi]OHCi = the C1-equivalent concentration of oxygenated 
          species i in diluted exhaust, not corrected for initial 
          contamination.
[chi]OHCi-init = the C1-equivalent concentration 
          of the initial system contamination (optional) of oxygenated 
          species i, dry-to-wet corrected.

[[Page 245]]

[chi]THC[THC-FID]cor = the C1-equivalent response 
          to NOTHC and all OHC in diluted exhaust, HC contamination and 
          dry-to-wet corrected, as measured by the THC-FID.
RFOHCi[THC-FID] = the response factor of the FID to species i 
          relative to propane on a C1-equivalent basis.
Mdexh = the molar mass of diluted exhaust as determine in 
          Sec.  1065.340.
mdexhOHCi = the mass of oxygenated species i in dilute 
          exhaust.
MOHCi = the C1-equivalent molecular weight of 
          oxygenated species i.
mdexh = the mass of diluted exhaust.
ndexhOHCi = the number of moles of oxygenated species i in 
          total diluted exhaust flow.
ndexh = the total diluted exhaust flow.
    (b) If we require you to determine nonmethane hydrocarbon equivalent 
(NMHCE), use the following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.226

Where:

xNMHCE = the sum of the C1-equivalent 
          concentrations of nonoxygenated nonmethane hydrocarbon 
          (NONMHC), alcohols, and aldehydes.
RFCH4[THC-FID] = the response factor of THC-FID to 
          CH4.
xCH4 = concentration of CH4, HC contamination 
          (optional) and dry-to-wet corrected, as measured by the gas 
          chromatograph FID.

    (c) The following example shows how to determine NMHCE emissions 
based on ethanol (C2H5OH), methanol 
(CH3OH), acetaldehyde (C2H4O), and 
formaldehyde (CH2O) as C1-equivalent molar 
concentrations:

xTHC[THC-FID]cor = 145.6 [micro]mol/mol
xCH4 = 18.9 [micro]mol/mol
xC2H5OH = 100.8 [micro]mol/mol
xCH3OH = 1.1 [micro]mol/mol
xC2H4O = 19.1 [micro]mol/mol
xCH2O = 1.3 [micro]mol/mol
RFCH4[THC-FID] = 1.07
RFC2H5OH[THC-FID] = 0.76
RFCH3OH[THC-FID] = 0.74
RFH2H4O[THC-FID] = 0.50
RFCH2O[THC-FID] = 0.0
xNMHCE = xTHC[THC-FID]cor - (xC2H5OH 
          [middot] RFC2H5OH[THC-FID] + xCH3OH 
          [middot] RFCH3OH[THC-FID] + xC2H4O 
          [middot] RFC2H4O[THC-FID] + xCH2O 
          [middot] RFCH2O[THC-FID]) + xC2H5OH + 
          xCH3OH + xC2H4O + xCH2O - 
          (RFCH4[THC-FID] [middot] xCH4)
xNMHCE = 145.6 - (100.8 [middot] 0.76 + 1.1 [middot] 0.74 + 
          19.1 [middot] 0.50 + 1.3 [middot] 0) + 100.8 + 1.1 + 19.1 + 
          1.3 - (1.07 [middot] 18.9)
xNMHCE = 160.71 [micro]mol/mol

[79 FR 23805, Apr. 28, 2014, as amended at 81 FR 74187, Oct. 25, 2016; 
86 FR 34567, June 29, 2021]



Sec.  1065.667  Dilution air background emission correction.

    (a) To determine the mass of background emissions to subtract from a 
diluted exhaust sample, first determine the total flow of dilution air, 
ndil, over the test interval. This may be a measured quantity 
or a calculated quantity. Multiply the total flow of dilution air by the 
mean mole fraction (i.e., concentration) of a background emission. This 
may be a time-weighted mean or a flow-weighted mean (e.g., a 
proportionally sampled background). Finally, multiply by the molar mass, 
M, of the associated gaseous emission constituent. The product of 
ndil and the mean molar concentration of a background 
emission and its molar mass, M, is the total background emission mass, 
m. In the case of PM, where the mean PM concentration is already in 
units of mass per mole of exhaust, multiply it by the total amount of 
dilution air flow, and the result is the total background mass of PM, 
mPM. Subtract total background mass from total mass to 
correct for background emissions.
    (b) You may determine the total flow of dilution air by a direct 
flow measurement.
    (c) You may determine the total flow of dilution air by subtracting 
the calculated raw exhaust molar flow as described in Sec.  1065.655(g) 
from the measured dilute exhaust flow. This may be done by totaling 
continuous calculations or by using batch results.

[[Page 246]]

    (d) You may determine the total flow of dilution air from the 
measured dilute exhaust flow and a chemical balance of the fuel, DEF, 
intake air, and dilute exhaust as described in Sec.  1065.655. For this 
paragraph (d), the molar flow of dilution air is calculated by 
multiplying the dilute exhaust flow by the mole fraction of dilution gas 
to dilute exhaust, [chi]dil/ex, from the dilute chemical 
balance. This may be done by totaling continuous calculations or by 
using batch results. For example, to use batch results, the total flow 
of dilution air is calculated by multiplying the total flow of diluted 
exhaust, ndexh, by the flow-weighted mean mole fraction of 
dilution air in diluted exhaust, [chi]dil/exh. Calculate 
[chi]dil/exh using flow-weighted mean concentrations of 
emissions in the chemical balance, as described in Sec.  1065.655. The 
chemical balance in Sec.  1065.655 assumes that your engine operates 
stoichiometrically, even if it is a lean-burn engine, such as a 
compression-ignition engine. Note that for lean-burn engines this 
assumption could result in an error in emission calculations. This error 
could occur because the chemical balance in Sec.  1065.655 treats excess 
air passing through a lean-burn engine as if it was dilution air. If an 
emission concentration expected at the standard is about 100 times its 
dilution air background concentration, this error is negligible. 
However, if an emission concentration expected at the standard is 
similar to its background concentration, this error could be 
significant. If this error might affect your ability to show that your 
engines comply with applicable standards in this chapter, we recommend 
that you either determine the total flow of dilution air using one of 
the more accurate methods in paragraph (b) or (c) of this section, or 
remove background emissions from dilution air by HEPA filtration, 
chemical adsorption, or catalytic scrubbing. You might also consider 
using a partial-flow dilution technique such as a bag mini-diluter, 
which uses purified air as the dilution air.
    (e) The following is an example of using the flow-weighted mean 
fraction of dilution air in diluted exhaust, xdil/exh, and 
the total mass of background emissions calculated using the total flow 
of diluted exhaust, ndexh, as described in Sec.  1065.650(c):
[GRAPHIC] [TIFF OMITTED] TR15SE11.075

    Example: 
MNOx = 46.0055 g/mol
xbkgnd = 0.05 [micro]mol/mol = 0.05[sdot]10-6 mol/
          mol
ndexh = 23280.5 mol
xdil/exh = 0.843 mol/mol
mbkgndNOxdexh = 
          46.0055[sdot]0.05[sdot]10-6[sdot]23280.5
mbkgndNOxdexh = 0.0536 g
mbkgndNOx = 0.843 [sdot] 0.0536
mbkgndNOx = 0.0452 g

    (f) The following is an example of using the fraction of dilution 
air in diluted exhaust, xdil/exh, and the mass rate of 
background emissions calculated using the flow rate of diluted exhaust, 
ndexh, as described in Sec.  1065.650(c):

[[Page 247]]

[GRAPHIC] [TIFF OMITTED] TR15SE11.076

    Example: 
MNOx = 46.0055 g/mol
xbkgnd = 0.05 [micro]mol/mol = 0.05[sdot]10-6 mol/
          mol
ndexh = 23280.5 mol/s
xdil/exh = 0.843 mol/mol
mbkgndNOxdexh = 
          46.0055[sdot]0.05[sdot]10-6[sdot]23280.5
mbkgndNOxdexh = 0.0536 g/hr
mbkgndNOx = 0.843 [sdot] 0.0536
mbkgndNOx = 0.0452 g/hr

[76 FR 57465, Sept. 15, 2011, as amended at 81 FR 74188, Oct. 25, 2016; 
86 FR 34567, June 29, 2021; 88 FR 4686, Jan. 24, 2023]



Sec.  1065.670  NOX intake-air humidity and temperature corrections.

    See the standard-setting part to determine if you may correct 
NOX emissions for the effects of intake-air humidity or 
temperature. Use the NOX intake-air humidity and temperature 
corrections specified in the standard-setting part instead of the 
NOX intake-air humidity correction specified in this part 
1065. If the standard-setting part does not prohibit correcting 
NOX emissions for intake-air humidity according to this part 
1065, correct NOX concentrations for intake-air humidity as 
described in this section. See Sec.  1065.650(c)(1) for the proper 
sequence for applying the NOX intake-air humidity and 
temperature corrections. You may use a time-weighted mean intake air 
humidity to calculate this correction if your intake air humidity 
remains within a tolerance of 0.0025 mol/mol of 
the mean value over the test interval. For intake-air humidity 
correction, use one of the following approaches:
    (a) For compression-ignition engines, correct for intake-air 
humidity using the following equation:
[GRAPHIC] [TIFF OMITTED] TR30AP10.095

    Example: 
xNOxuncor = 700.5 [micro]mol/mol
xH2O = 0.022 mol/mol
xNOxcor = 700.5 [middot] (9.953 [middot] 0.022 + 0.832)
xNOxcor = 736.2 [micro]mol/mol

    (b) For spark-ignition engines, correct for intake-air humidity 
using the following equation:
[GRAPHIC] [TIFF OMITTED] TR30AP10.096

    Example: 
xNOxuncor = 154.7 [micro]mol/mol
xH2O = 0.022 mol/mol
xNOxcor = 154.7 [middot] (18.840 [middot] 0.022 + 0.68094)
xNOxcor = 169.5 [micro]mol/mol

    (c) Develop your own correction, based on good engineering judgment.

[75 FR 23056, Apr. 30, 2010, as amended at 76 FR 57466, Sept. 15, 2011; 
88 FR 4686, Jan. 24, 2023]

[[Page 248]]



Sec.  1065.672  Drift correction.

    (a) Scope and frequency. Perform the calculations in this section to 
determine if gas analyzer drift invalidates the results of a test 
interval. If drift does not invalidate the results of a test interval, 
correct that test interval's gas analyzer responses for drift according 
to this section. Use the drift-corrected gas analyzer responses in all 
subsequent emission calculations. Note that the acceptable threshold for 
gas analyzer drift over a test interval is specified in Sec.  1065.550 
for both laboratory testing and field testing.
    (b) Correction principles. The calculations in this section utilize 
a gas analyzer's responses to reference zero and span concentrations of 
analytical gases, as determined sometime before and after a test 
interval. The calculations correct the gas analyzer's responses that 
were recorded during a test interval. The correction is based on an 
analyzer's mean responses to reference zero and span gases, and it is 
based on the reference concentrations of the zero and span gases 
themselves. Validate and correct for drift as follows:
    (c) Drift validation. After applying all the other corrections--
except drift correction--to all the gas analyzer signals, calculate 
brake-specific emissions according to Sec.  1065.650. Then correct all 
gas analyzer signals for drift according to this section. Recalculate 
brake-specific emissions using all of the drift-corrected gas analyzer 
signals. Validate and report the brake-specific emission results before 
and after drift correction according to Sec.  1065.550.
    (d) Drift correction. Correct all gas analyzer signals as follows:
    (1) Correct each recorded concentration, xi, for 
continuous sampling or for batch sampling, x.
    (2) Correct for drift using the following equation:
    [GRAPHIC] [TIFF OMITTED] TR24FE09.005
    
Where:

xidriftcorrected = concentration corrected for drift.
xrefzero = reference concentration of the zero gas, which is 
          usually zero unless known to be otherwise.
xrefspan = reference concentration of the span gas.
xprespan = pre-test interval gas analyzer response to the 
          span gas concentration.
xpostspan = post-test interval gas analyzer response to the 
          span gas concentration.
xi or x = concentration recorded during test, before drift 
          correction.
xprezero = pre-test interval gas analyzer response to the 
          zero gas concentration.
xpostzero = post-test interval gas analyzer response to the 
          zero gas concentration.

    Example: 
xrefzero = 0 [micro]mol/mol
xrefspan = 1800.0 [micro]mol/mol
xprespan = 1800.5 [micro]mol/mol
xpostspan = 1695.8 [micro]mol/mol
xi or x = 435.5 [micro]mol/mol
xprezero = 0.6 [micro]mol/mol
xpostzero = -5.2 [micro]mol/mol
[GRAPHIC] [TIFF OMITTED] TR24FE09.006

xidriftcorrected = 450.2 [micro]mol/mol

    (3) For any pre-test interval concentrations, use the last 
concentration determined before the test interval. For some test 
intervals, the last pre-zero or pre-span might have occurred

[[Page 249]]

before one or more earlier test intervals.
    (4) For any post-test interval concentrations, use the first 
concentration determined after the test interval. For some test 
intervals, the first post-zero or post-span might occur after one or 
more later test intervals.
    (5) If you do not record any pre-test interval analyzer response to 
the span gas concentration, xprespan, set xprespan 
equal to the reference concentration of the span gas:

xprespan = xrefspan.

    (6) If you do not record any pre-test interval analyzer response to 
the zero gas concentration, xprezero, set xprezero 
equal to the reference concentration of the zero gas:

xprezero = xrefzero.

    (7) Usually the reference concentration of the zero gas, 
xrefzero, is zero: xrefzero = 0 [micro]mol/mol. 
However, in some cases you might know that xrefzero has a 
non-zero concentration. For example, if you zero a CO2 
analyzer using ambient air, you may use the default ambient air 
concentration of CO2, which is 375 [micro]mol/mol. In this 
case, xrefzero = 375 [micro]mol/mol. Note that when you zero 
an analyzer using a non-zero xrefzero, you must set the 
analyzer to output the actual xrefzero concentration. For 
example, if xrefzero = 375 [micro]mol/mol, set the analyzer 
to output a value of 375 [micro]mol/mol when the zero gas is flowing to 
the analyzer.

[70 FR 40516, July 13, 2005, as amended at 74 FR 8427, Feb. 24, 2009; 75 
FR 23056, Apr. 30, 2010; 88 FR 4686, Jan. 24, 2023]



Sec.  1065.675  CLD quench verification calculations.

    Perform CLD quench-check calculations as follows:
    (a) Perform a CLD analyzer quench verification test as described in 
Sec.  1065.370.
    (b) Estimate the maximum expected mole fraction of water during 
emission testing, xH2Oexp. Make this estimate where the 
humidified NO span gas was introduced in Sec.  1065.370(e)(6). When 
estimating the maximum expected mole fraction of water, consider the 
maximum expected water content in intake air, fuel combustion products, 
and dilution air (if applicable). If you introduced the humidified NO 
span gas into the sample system upstream of a sample dryer during the 
verification test, you need not estimate the maximum expected mole 
fraction of water and you must set xH2Oexp equal to 
xH2Omeas.
    (c) Estimate the maximum expected CO2 concentration 
during emission testing, xCO2exp. Make this estimate at the 
sample system location where the blended NO and CO2 span 
gases are introduced according to Sec.  1065.370(d)(10). When estimating 
the maximum expected CO2 concentration, consider the maximum 
expected CO2 content in fuel combustion products and dilution 
air.
    (d) Calculate quench as follows:
    [GRAPHIC] [TIFF OMITTED] TR29JN21.259
    
Where:

quench = amount of CLD quench.
[chi]NOdry = concentration of NO upstream of a humidity 
          generator, according to Sec.  1065.370(e)(4).

[[Page 250]]

[chi]NOwet = measured concentration of NO downstream of a 
          humidity generator, according to Sec.  1065.370(e)(9).
[chi]H2Oexp = maximum expected mole fraction of water during 
          emission testing, according to paragraph (b) of this section.
[chi]H2Omeas = measured mole fraction of water during the 
          quench verification, according to Sec.  1065.370(e)(7).
[chi]NOmeas = measured concentration of NO when NO span gas 
          is blended with CO2 span gas, according to Sec.  
          1065.370(d)(10).
[chi]NOact = actual concentration of NO when NO span gas is 
          blended with CO2 span gas, according to Sec.  
          1065.370(d)(11) and calculated according to Eq. 1065.675-2.
[chi]CO2exp = maximum expected concentration of 
          CO2 during emission testing, according to paragraph 
          (c) of this section.
[chi]CO2act = actual concentration of CO2 when NO 
          span gas is blended with CO2 span gas, according to 
          Sec.  1065.370(d)(9).
          [GRAPHIC] [TIFF OMITTED] TR29JN21.260
          
Where:

[chi]NOspan = the NO span gas concentration input to the gas 
          divider, according to Sec.  1065.370(d)(5).
[chi]CO2span = the CO2 span gas concentration 
          input to the gas divider, according to Sec.  1065.370(d)(4).
    Example: 
[chi]NOdry = 1800.0 [micro]mol/mol
[chi]NOwet = 1739.6 [micro]mol/mol
[chi]H2Oexp = 0.030 mol/mol
[chi]H2Omeas = 0.030 mol/mol
[chi]NOmeas = 1515.2 [micro]mol/mol
[chi]NOspan = 3001.6 [micro]mol/mol
[chi]CO2exp = 3.2%
[chi]CO2span = 6.1%
[chi]CO2act = 2.98%
[GRAPHIC] [TIFF OMITTED] TR29JN21.261

quench = (-0.0036655-0.014020171) [middot] 100% = -1.7685671%

[73 FR 59340, Oct. 8, 2008, as amended at 76 FR 57466, Sept. 15, 2011; 
81 FR 74188, Oct. 25, 2016; 86 FR 34568, June 29, 2021; 88 FR 4686, Jan. 
24, 2023]



Sec.  1065.680  Adjusting emission levels to account for infrequently
regenerating aftertreatment devices.

    This section describes how to calculate and apply emission 
adjustment factors for engines using aftertreatment technology with 
infrequent regeneration events that may occur during testing. These 
adjustment factors are typically calculated based on measurements 
conducted for the purposes of engine certification, and then used to 
adjust the results of testing related to demonstrating compliance with 
emission standards. For this

[[Page 251]]

section, ``regeneration'' means an intended event during which emission 
levels change while the system restores aftertreatment performance. For 
example, exhaust gas temperatures may increase temporarily to remove 
sulfur from an adsorber or SCR catalyst or to oxidize accumulated 
particulate matter in a trap. The duration of this event extends until 
the aftertreatment performance and emission levels have returned to 
normal baseline levels. Also, ``infrequent'' refers to regeneration 
events that are expected to occur on average less than once over a 
transient or ramped-modal duty cycle, or on average less than once per 
mode in a discrete-mode test.
    (a) Apply adjustment factors based on whether there is active 
regeneration during a test segment. The test segment may be a test 
interval or a full duty cycle, as described in paragraph (b) of this 
section. For engines subject to standards over more than one duty cycle, 
you must develop adjustment factors under this section for each separate 
duty cycle. You must be able to identify active regeneration in a way 
that is readily apparent during all testing. All adjustment factors for 
regeneration are additive.
    (1) If active regeneration does not occur during a test segment, 
apply an upward adjustment factor, UAF, that will be added to the 
measured emission rate for that test segment. Use the following equation 
to calculate UAF:

[GRAPHIC] [TIFF OMITTED] TR25OC16.318

Where:

EFA[cycle] = the average emission factor over the test 
          segment as determined in paragraph (a)(4) of this section.
EFL[cycle] = measured emissions over a complete test segment 
          in which active regeneration does not occur.

    Example: 
EFARMC = 0.15 g/kW[middot]hr
EFLRMC = 0.11 g/kW[middot]hr
UAFRMC = 0.15 - 0.11 = 0.04 g/kW[middot]hr

    (2) If active regeneration occurs or starts to occur during a test 
segment, apply a downward adjustment factor, DAF, that will be 
subtracted from the measured emission rate for that test segment. Use 
the following equation to calculate DAF:
[GRAPHIC] [TIFF OMITTED] TR25OC16.230

Where:

EFH[cycle] = measured emissions over the test segment from a 
          complete regeneration event, or the average emission rate over 
          multiple complete test segments with regeneration if the 
          complete regeneration event lasts longer than one test 
          segment.

    Example: 
EFARMC = 0.15 g/kW[middot]hr
EFHRMC = 0.50 g/kW[middot]hr
DAFRMC = 0.50 - 0.15 = 0.35 g/kW[middot]hr

    (3) Note that emissions for a given pollutant may be lower during 
regeneration, in which case EFL would be greater than 
EFH, and both UAF and DAF would be negative.
    (4) Calculate the average emission factor, EFA, as 
follows:

[[Page 252]]

[GRAPHIC] [TIFF OMITTED] TR25OC16.231

Where:

F[cycle] = the frequency of the regeneration event during the 
          test segment, expressed in terms of the fraction of equivalent 
          test segments during which active regeneration occurs, as 
          described in paragraph (a)(5) of this section.
    Example: 
FRMC = 0.10
EFARMC = 0.10 [middot] 0.50 + (1.00 - 0.10) [middot] 0.11 = 
          0.15 g/kW[middot]hr

    (5) The frequency of regeneration, F, generally characterizes how 
often a regeneration event occurs within a series of test segments. 
Determine F using the following equation, subject to the provisions of 
paragraph (a)(6) of this section:
[GRAPHIC] [TIFF OMITTED] TR25OC16.232

Where:

ir[cycle] = the number of successive test segments required 
          to complete an active regeneration, rounded up to the next 
          whole number.
if[cycle] = the number of test segments from the end of one 
          complete regeneration event to the start of the next active 
          regeneration, without rounding.

    Example: 
irRMC = 2
ifRMC = 17.86
[GRAPHIC] [TIFF OMITTED] TR25OC16.233

    (6) Use good engineering judgment to determine ir and 
if, as follows:
    (i) For engines that are programmed to regenerate after a specific 
time interval, you may determine the duration of a regeneration event 
and the time between regeneration events based on the engine's design 
parameters. For other engines, determine these values based on 
measurements from in-use operation or from running repetitive duty 
cycles in a laboratory.
    (ii) For engines subject to standards over multiple duty cycles, 
such as for transient and steady-state testing, apply this same 
calculation to determine a value of F for each duty cycle.
    (iii) Consider an example for an engine that is designed to 
regenerate its PM filter 500 minutes after the end of the last 
regeneration event, with the regeneration event lasting 30 minutes. If 
the RMC takes 28 minutes, irRMC = 2 (30 / 28 = 1.07, which 
rounds up to 2), and ifRMC = 500 / 28 = 17.86.
    (b) Develop adjustment factors for different types of testing as 
follows:

[[Page 253]]

    (1) Discrete-mode testing. Develop separate adjustment factors for 
each test mode (test interval) of a discrete-mode test. When measuring 
EFH, if a regeneration event has started but is not complete 
when you reach the end of the sampling time for a test interval, extend 
the sampling period for that test interval until the regeneration event 
is complete.
    (2) Ramped-modal and transient testing. Develop a separate set of 
adjustment factors for an entire ramped-modal cycle or transient duty 
cycle. When measuring EFH, if a regeneration event has 
started but is not complete when you reach the end of the duty cycle, 
start the next repeat test as soon as possible, allowing for the time 
needed to complete emission measurement and installation of new filters 
for PM measurement; in that case EFH is the average emission 
level for the test segments that included regeneration.
    (3) Accounting for cold-start measurements. For engines subject to 
cold-start testing requirements, incorporate cold-start operation into 
your analysis as follows:
    (i) Determine the frequency of regeneration, F, in a way that 
incorporates the impact of cold-start operation in proportion to the 
cold-start weighting factor specified in the standard-setting part. You 
may use good engineering judgment to determine the effect of cold-start 
operation analytically.
    (ii) Treat cold-start testing and hot-start testing together as a 
single test segment for adjusting measured emission results under this 
section. Apply the adjustment factor to the composite emission result.
    (iii) You may apply the adjustment factor only to the hot-start test 
result if your aftertreatment technology does not regenerate during cold 
operation as represented by the cold-start transient duty cycle. If we 
ask for it, you must demonstrate this by engineering analysis or by test 
data.
    (c) If an engine has multiple regeneration strategies, determine and 
apply adjustment factors under this section separately for each type of 
regeneration.

[81 FR 74189, Oct. 25, 2016, as amended at 88 FR 4686, Jan. 24, 2023]



Sec.  1065.690  Buoyancy correction for PM sample media.

    (a) General. Correct PM sample media for their buoyancy in air if 
you weigh them on a balance. The buoyancy correction depends on the 
sample media density, the density of air, and the density of the 
calibration weight used to calibrate the balance. The buoyancy 
correction does not account for the buoyancy of the PM itself, because 
the mass of PM typically accounts for only (0.01 to 0.10)% of the total 
weight. A correction to this small fraction of mass would be at the most 
0.010%.
    (b) PM sample media density. Different PM sample media have 
different densities. Use the known density of your sample media, or use 
one of the densities for some common sampling media, as follows:
    (1) For PTFE-coated borosilicate glass, use a sample media density 
of 2300 kg/m\3\.
    (2) For PTFE membrane (film) media with an integral support ring of 
polymethylpentene that accounts for 95% of the media mass, use a sample 
media density of 920 kg/m\3\.
    (3) For PTFE membrane (film) media with an integral support ring of 
PTFE, use a sample media density of 2144 kg/m\3\.
    (c) Air density. Because a PM balance environment must be tightly 
controlled to an ambient temperature of (22 1) 
[deg]C and humidity has an insignificant effect on buoyancy correction, 
air density is primarily a function of atmospheric pressure. Therefore 
you may use nominal constant values for temperature and humidity when 
determining the air density of the balance environment in Eq. 1065.690-
2.
    (d) Calibration weight density. Use the stated density of the 
material of your metal calibration weight. The example calculation in 
this section uses a density of 8000 kg/m\3\, but you should know the 
density of your weight from the calibration weight supplier or the 
balance manufacturer if it is an internal weight.
    (e) Correction calculation. Correct the PM sample media for buoyancy 
using the following equations:

[[Page 254]]

[GRAPHIC] [TIFF OMITTED] TR28AP14.055

Where:

mcor = PM mass corrected for buoyancy.
muncor = PM mass uncorrected for buoyancy.
rair = density of air in balance environment.
rweight = density of calibration weight used to span balance.
rmedia = density of PM sample media, such as a filter.
[GRAPHIC] [TIFF OMITTED] TR28AP14.056

Where:

pabs = absolute pressure in balance environment.
Mmix = molar mass of air in balance environment.
R = molar gas constant.
Tamb = absolute ambient temperature of balance environment.

[[Page 255]]

[GRAPHIC] [TIFF OMITTED] TR28AP14.057


[[Page 256]]


[GRAPHIC] [TIFF OMITTED] TR28AP14.058


[70 FR 40516, July 13, 2005, as amended at 73 FR 37339, June 30, 2008; 
75 FR 23056, Apr. 30, 2010; 79 FR 23805, Apr. 28, 2014; 81 FR 74191, 
Oct. 25, 2016]



Sec.  1065.695  Data requirements.

    (a) To determine the information we require from engine tests, refer 
to the standard-setting part and request from your EPA Program Officer 
the format used to apply for certification or demonstrate compliance. We 
may require different information for different purposes, such as for 
certification applications, approval requests for alternate procedures, 
selective enforcement audits, laboratory audits, production-line test 
reports, and field-test reports.
    (b) See the standard-setting part and Sec.  1065.25 regarding 
recordkeeping.
    (c) We may ask you the following about your testing, and we may ask 
you for other information as allowed under the Act:
    (1) What approved alternate procedures did you use? For example:
    (i) Partial-flow dilution for proportional PM.
    (ii) CARB test procedures.
    (iii) ISO test procedures.
    (2) What laboratory equipment did you use? For example, the make, 
model, and description of the following:
    (i) Engine dynamometer and operator demand.
    (ii) Probes, dilution, transfer lines, and sample preconditioning 
components.
    (iii) Batch storage media (such as the bag material or PM filter 
material).
    (3) What measurement instruments did you use? For example, the make, 
model, and description of the following:
    (i) Speed and torque instruments.
    (ii) Flow meters.
    (iii) Gas analyzers.
    (iv) PM balance.
    (4) When did you conduct calibrations and performance checks and 
what were the results? For example, the dates and results of the 
following:
    (i) Linearity verification.
    (ii) Interference checks.
    (iii) Response checks.
    (iv) Leak checks.
    (v) Flow meter checks.
    (5) What engine did you test? For example, the following:
    (i) Manufacturer.
    (ii) Family name on engine label.
    (iii) Model.
    (iv) Model year.
    (v) Identification number.
    (6) How did you prepare and configure your engine for testing? 
Consider the following examples:
    (i) Dates, hours, duty cycle and fuel used for service accumulation.
    (ii) Dates and description of scheduled and unscheduled maintenance.
    (iii) Allowable pressure range of intake restriction.
    (iv) Allowable pressure range of exhaust restriction.
    (v) Charge air cooler volume.
    (vi) Charge air cooler outlet temperature, specified engine 
conditions and location of temperature measurement.
    (vii) Fuel temperature and location of measurement.
    (viii) Any aftertreatment system configuration and description.
    (ix) Any crankcase ventilation configuration and description (e.g., 
open, closed, PCV, crankcase scavenged).
    (x) Number and type of preconditioning cycles.
    (7) How did you test your engine? For example:
    (i) Constant speed or variable speed.
    (ii) Mapping procedure (step or sweep).

[[Page 257]]

    (iii) Continuous or batch sampling for each emission.
    (iv) Raw or dilute sampling; any dilution-air background sampling.
    (v) Duty cycle and test intervals.
    (vi) Cold-start, hot-start, warmed-up running.
    (vii) Absolute pressure, temperature, and dewpoint of intake and 
dilution air.
    (viii) Simulated engine loads, curb idle transmission torque value.
    (ix) Warm-idle speed value.
    (x) Simulated vehicle signals applied during testing.
    (xi) Bypassed governor controls during testing.
    (xii) Date, time, and location of test (e.g., dynamometer laboratory 
identification).
    (xiii) Cooling medium for engine and charge air.
    (xiv) Operating temperatures of coolant, head, and block.
    (xv) Natural or forced cool-down and cool-down time.
    (xvi) Canister loading.
    (8) How did you validate your testing? For example, results from the 
following:
    (i) Duty cycle regression statistics for each test interval.
    (ii) Proportional sampling.
    (iii) Drift.
    (iv) Reference PM sample media in PM-stabilization environment.
    (v) Carbon balance error verification, if performed.
    (9) How did you calculate results? For example, results from the 
following:
    (i) Drift correction.
    (ii) Noise correction.
    (iii) ``Dry-to-wet'' correction.
    (iv) NMHC, CH4, and contamination correction.
    (v) NOX humidity correction.
    (vi) Brake-specific emission formulation--total mass divided by 
total work, mass rate divided by power, or ratio of mass to work.
    (vii) Rounding emission results.
    (10) What were the results of your testing? For example:
    (i) Maximum mapped power and speed at maximum power.
    (ii) Maximum mapped torque and speed at maximum torque.
    (iii) For constant-speed engines: no-load governed speed.
    (iv) For constant-speed engines: test torque.
    (v) For variable-speed engines: maximum test speed.
    (vi) Speed versus torque map.
    (vii) Speed versus power map.
    (viii) Brake-specific emissions over the duty cycle and each test 
interval.
    (ix) Brake-specific fuel consumption.
    (11) What fuel did you use? For example:
    (i) Fuel that met specifications of subpart H of this part.
    (ii) Alternate fuel.
    (iii) Oxygenated fuel.
    (12) How did you field test your engine? For example:
    (i) Data from paragraphs (c)(1), (3), (4), (5), and (9) of this 
section.
    (ii) Probes, dilution, transfer lines, and sample preconditioning 
components.
    (iii) Batch storage media (such as the bag material or PM filter 
material).
    (iv) Continuous or batch sampling for each emission.
    (v) Raw or dilute sampling; any dilution air background sampling.
    (vi) Cold-start, hot-start, warmed-up running.
    (vii) Intake and dilution air absolute pressure, temperature, 
dewpoint.
    (viii) Curb idle transmission torque value.
    (ix) Warm idle speed value, any enhanced-idle speed value.
    (x) Date, time, and location of test (e.g., identify the testing 
laboratory).
    (xi) Proportional sampling validation.
    (xii) Drift validation.
    (xiii) Operating temperatures of coolant, head, and block.
    (xiv) Vehicle make, model, model year, identification number.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37339, June 30, 2008; 
79 FR 23807, Apr. 28, 2014; 86 FR 34568, June 29, 2021; 88 FR 4687, Jan. 
24, 2023]



    Subpart H_Engine Fluids, Test Fuels, Analytical Gases and Other 
                          Calibration Standards



Sec.  1065.701  General requirements for test fuels.

    (a) General. For all emission measurements, use test fuels that meet 
the specifications in this subpart, unless

[[Page 258]]

the standard-setting part directs otherwise. Section 1065.10(c)(1) does 
not apply with respect to test fuels. Note that the standard-setting 
parts generally require that you design your emission controls to 
function properly when using commercially available fuels, even if they 
differ from the test fuel. Where we specify multiple grades of a certain 
fuel type (such as diesel fuel with different sulfur concentrations), 
see the standard-setting part to determine which grade to use.
    (b) Fuels meeting alternate specifications. We may allow you to use 
a different test fuel (such as California LEV III gasoline) if it does 
not affect your ability to show that your engines would comply with all 
applicable emission standards in this chapter using the test fuel 
specified in this subpart.
    (c) Fuels not specified in this subpart. If you produce engines that 
run on a type of fuel (or mixture of fuels) that we do not specify in 
this subpart, you must get our written approval to establish the 
appropriate test fuel. See the standard-setting part for provisions 
related to fuels and fuel mixtures not specified in this subpart.
    (1) For engines designed to operate on a single fuel, we will 
generally allow you to use the fuel if you show us all the following 
things are true:
    (i) Show that your engines will use only the designated fuel in 
service.
    (ii) Show that this type of fuel is commercially available.
    (iii) Show that operating the engines on the fuel we specify would 
be inappropriate, as in the following examples:
    (A) The engine will not run on the specified fuel.
    (B) The engine or emission controls will not be durable or work 
properly when operating with the specified fuel.
    (C) The measured emission results would otherwise be substantially 
unrepresentative of in-use emissions.
    (2) For engines that are designed to operate on different fuel 
types, the provisions of paragraphs (c)(1)(ii) and (iii) of this section 
apply with respect to each fuel type.
    (3) For engines that are designed to operate on different fuel types 
as well as continuous mixtures of those fuels, we may require you to 
test with either the worst-case fuel mixture or the most representative 
fuel mixture, unless the standard-setting part specifies otherwise.
    (d) Fuel specifications. Specifications in this section apply as 
follows:
    (1) Measure and calculate values as described in the appropriate 
reference procedure. Record and report final values expressed to at 
least the same number of decimal places as the applicable limit value. 
The right-most digit for each limit value is significant unless 
specified otherwise. For example, for a specified distillation 
temperature of 60 [deg]C, determine the test fuel's value to at least 
the nearest whole number.
    (2) The fuel parameters specified in this subpart depend on 
measurement procedures that are incorporated by reference. For any of 
these procedures, you may instead rely upon the procedures identified in 
40 CFR part 1090 for measuring the same parameter. For example, we may 
identify different reference procedures for measuring gasoline 
parameters in 40 CFR 1090.1360.
    (e) Two-stroke fuel/oil mixing. For two-stroke engines, use a fuel/
oil mixture meeting the manufacturer's specifications.
    (f) Service accumulation and field testing fuels. If we do not 
specify a service-accumulation or field-testing fuel in the standard-
setting part, use an appropriate commercially available fuel such as 
those meeting minimum specifications from the following table:

 Table 1 of Sec.   1065.701--Examples of Service-Accumulation and Field-
                              Testing Fuels
------------------------------------------------------------------------
                                                           Reference
          Fuel category               Subcategory        procedure \a\
------------------------------------------------------------------------
Diesel..........................  Light distillate    ASTM D975.
                                   and light blends
                                   with residual.
                                  Middle distillate.  ASTM D6985.
                                  Biodiesel (B100)..  ASTM D6751.
Intermediate and residual fuel..  All...............  See Sec.
                                                       1065.705.
Gasoline........................  Automotive          ASTM D4814.
                                   gasoline.
                                  Automotive          ASTM D4814.
                                   gasoline with
                                   ethanol
                                   concentration up
                                   to 10 volume %.
Alcohol.........................  Ethanol (E51-83)..  ASTM D5798.
                                  Methanol (M70-M85)  ASTM D5797.
Aviation fuel...................  Aviation gasoline.  ASTM D910.
                                  Gas turbine.......  ASTM D1655.
                                  Jet B wide cut....  ASTM D6615.
Gas turbine fuel................  General...........  ASTM D2880.
------------------------------------------------------------------------
\a\ Incorporated by reference; see Sec.   1065.1010.


[[Page 259]]


[70 FR 40516, July 13, 2005, as amended at 73 FR 37339, June 30, 2008; 
73 FR 59341, Oct. 8, 2008; 75 FR 23057, Apr. 30, 2010;79 FR 23807, Apr. 
28, 2014; 85 FR 78468, Dec. 4, 2020; 86 FR 34568, June 29, 2021]



Sec.  1065.703  Distillate diesel fuel.

    (a) Distillate diesel fuels for testing must be clean and bright, 
with pour and cloud points adequate for proper engine operation.
    (b) There are three grades of 2 diesel fuel specified for use as a 
test fuel. See the standard-setting part to determine which grade to 
use. If the standard-setting part does not specify which grade to use, 
use good engineering judgment to select the grade that represents the 
fuel on which the engines will operate in use. The three grades are 
specified in Table 1 of this section.

                 Table 1 of Sec.   1065.703--Test Fuel Specifications for Distillate Diesel Fuel
----------------------------------------------------------------------------------------------------------------
                                                  Ultra low                                        Reference
            Property                 Unit          sulfur        Low sulfur      High sulfur      procedure a
----------------------------------------------------------------------------------------------------------------
Cetane Number..................  ............           40-50           40-50           40-50  ASTM D613.
Distillation range:
    Initial boiling point......   [deg]C.....         171-204         171-204         171-204  ASTM D86.
    10 pct. point..............  ............         204-238         204-238         204-238
    50 pct. point..............  ............         243-282         243-282         243-282
    90 pct. point..............  ............         293-332         293-332         293-332
    Endpoint...................  ............         321-366         321-366         321-366
Gravity........................  [deg]API....           32-37           32-37           32-37  ASTM D4052.
Total sulfur...................  mg/kg.......            7-15         300-500        800-2500  ASTM D2622, ASTM
                                                                                                D5453, or ASTM
                                                                                                D7039.
Aromatics, min. (Remainder       g/kg........             100             100             100  ASTM D5186.
 shall be paraffins,
 naphthenes, and olefins).
Flashpoint, min................   [deg]C.....              54              54              54  ASTM D93.
Kinematic Viscosity............  mm\2\/s.....         2.0-3.2         2.0-3.2         2.0-3.2  ASTM D445.
----------------------------------------------------------------------------------------------------------------
\a\ Incorporated by reference, see Sec.   1065.1010. See Sec.   1065.701(d) for other allowed procedures.

    (c) You may use the following nonmetallic additives with distillate 
diesel fuels:
    (1) Cetane improver.
    (2) Metal deactivator.
    (3) Antioxidant, dehazer.
    (4) Rust inhibitor.
    (5) Pour depressant.
    (6) Dye.
    (7) Dispersant.
    (8) Biocide.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37340, June 30, 2008; 
73 FR 59341, Oct. 8, 2008; 75 FR 23057, Apr. 30, 2010; 77 FR 2464, Jan. 
18, 2012;79 FR 23807, Apr. 28, 2014; 85 FR 78468, Dec. 4, 2020; 86 FR 
34569, June 29, 2021]



Sec.  1065.705  Residual and intermediate residual fuel.

    This section describes the specifications for fuels meeting the 
definition of residual fuel in 40 CFR 1090.80, including fuels marketed 
as intermediate fuel. Residual fuels for service accumulation and any 
testing must meet the following specifications:
    (a) The fuel must be a commercially available fuel that is 
representative of the fuel that will be used by the engine in actual 
use.
    (b) The fuel must be free of used lubricating oil. Demonstrate this 
by showing that the fuel meets at least one of the following 
specifications.
    (1) Zinc is at or below 15 mg per kg of fuel based on the procedures 
specified in IP470, IP501, or ISO 8217 (incorporated by reference in 
Sec.  1065.1010).
    (2) Phosphorus is at or below 15 mg per kg of fuel based on the 
procedures specified in IP500, IP501, or ISO 8217 (incorporated by 
reference in Sec.  1065.1010).
    (3) Calcium is at or below 30 mg per kg of fuel based on the 
procedures specified in IP470, IP501, or ISO 8217 (incorporated by 
reference in Sec.  1065.1010).
    (c) The fuel must meet the specifications for one of the categories 
in the following table:

[[Page 260]]

[GRAPHIC] [TIFF OMITTED] TR29JN21.262


[79 FR 23808, Apr. 28, 2014, as amended at 85 FR 78468, Dec. 4, 2020; 86 
FR 34569, June 29, 2021]

[[Page 261]]



Sec.  1065.710  Gasoline.

    (a) This section specifies test fuel properties for gasoline with 
ethanol (low-level blend only) and for gasoline without ethanol. Note 
that the ``fuel type'' for the fuels specified in paragraphs (b) and (c) 
of this section is considered to be gasoline. In contrast, fuels with 
higher ethanol concentrations, such as fuel containing 82 percent 
ethanol, are considered to be ethanol fuels rather than gasoline. We 
specify some test fuel parameters that apply uniquely for low-
temperature testing and for testing at altitudes above 1,219 m. For all 
other testing, use the test fuel parameters specified for general 
testing. Unless the standard-setting part specifies otherwise, use the 
fuel specified in paragraph (c) of this section for general testing.
    (b) The following specifications apply for a blended gasoline test 
fuel that has nominally 10% ethanol (commonly called E10 test fuel):
    (1) Prepare the blended test fuel from typical refinery gasoline 
blending components. You may not use pure compounds, except as follows:
    (i) You may use neat ethanol as a blendstock.
    (ii) You may adjust the test fuel's vapor pressure by adding butane.
    (iii) You may adjust the test fuel's benzene content by adding 
benzene.
    (iv) You may adjust the test fuel's sulfur content by adding sulfur 
compounds that are representative of those found with in-use fuels.
    (2) Table 1 of this section identifies limit values consistent with 
the units in the reference procedure for each fuel property. These 
values are generally specified in international units. Values presented 
in parentheses are for information only. Table 1 follows:

[[Page 262]]

[GRAPHIC] [TIFF OMITTED] TR29JN21.263

    (3) The ethanol-blended specification in Table 1 of this section is 
based on the volume % ethanol content of the fuel as determined during 
blending by the fuel supplier and as stated by the supplier at the time 
of fuel delivery. Use good engineering judgment to determine the volume 
% of ethanol based

[[Page 263]]

on the volume of each blendstock. We recommend using a flow-based or 
gravimetric procedure that has an accuracy and repeatability of 0.1%.
    (c) The specifications of this paragraph (c) apply for testing with 
neat gasoline. This is sometimes called indolene or E0 test fuel. 
Gasoline for testing must have octane values that represent commercially 
available fuels for the appropriate application. Test fuel 
specifications apply as follows:

                   Table 2 of Sec.   1065.710--Test Fuel Specifications for Neat (E0) Gasoline
----------------------------------------------------------------------------------------------------------------
                                                                 Specification
                                                  ------------------------------------------ Reference procedure
             Property                   Unit                              Low-temperature             a
                                                     General testing          testing
----------------------------------------------------------------------------------------------------------------
Distillation Range:
    Evaporated initial boiling      [deg]C.......  24-35 \b\..........  24-36..............  ASTM D86.
     point.
    10% evaporated...............   [deg]C.......  49-57..............  37-48..............
    50% evaporated...............   [deg]C.......  93-110.............  82-101.............
    90% evaporated...............   [deg]C.......  149-163............  158-174............
    Evaporated final boiling        [deg]C.......  Maximum, 213.......  Maximum, 212.......
     point.
Total Aromatic Hydrocarbons......  volume %......  Maximum, 35........  Maximum, 30.4......  ASTM D1319 or ASTM
                                                                                              D5769.
Olefins \c\......................  volume %......  Maximum, 10........  Maximum, 17.5......  ASTM D1319 or ASTM
                                                                                              D6550.
Lead.............................  g/liter.......  Maximum, 0.013.....  Maximum, 0.013.....  ASTM D3237.
Phosphorous......................  g/liter.......  Maximum, 0.0013....  Maximum, 0.005.....  ASTM D3231.
Total sulfur.....................  mg/kg.........  Maximum, 80........  Maximum, 80........  ASTM D2622.
Dry vapor pressure equivalent \d\  kPa...........  60.0-63.4 b e......  77.2-81.4..........  ASTM D5191.
----------------------------------------------------------------------------------------------------------------
\a\ Incorporated by reference; see Sec.   1065.1010. See Sec.   1065.701(d) for other allowed procedures.
\b\ For testing at altitudes above 1219 m, the specified initial boiling point range is (23.9 to 40.6) [deg]C
  and the specified volatility range is (52.0 to 55.2) kPa.
\c\ ASTM D6550 prescribes measurement of olefin concentration in mass %. Multiply this result by 0.857 and round
  to the first decimal place to determine the olefin concentration in volume %.
\d\ Calculate dry vapor pressure equivalent, DVPE, based on the measured total vapor pressure, pT, in kPa using
  the following equation: DVPE(kPa) = 0.956[middot]pT - 2.39 or DVPE(psi) = 0.956[middot]pT - 0.347. DVPE is
  intended to be equivalent to Reid Vapor Pressure using a different test method.
\e\ For testing unrelated to evaporative emissions, the specified range is (55.2 to 63.4) kPa.

    (d) Use the high-octane gasoline specified in paragraph (b) of this 
section only for engines or vehicles for which the manufacturer 
conditions the warranty on the use of premium gasoline.

[79 FR 23809, Apr. 28, 2014, as amended at 80 FR 9119, Feb. 19, 2015; 86 
FR 34571, June 29, 2021]



Sec.  1065.715  Natural gas.

    (a) Except as specified in paragraph (b) of this section, natural 
gas for testing must meet the specifications in the following table:

  Table 1 of Sec.   1065.715--Test Fuel Specifications for Natural Gas
------------------------------------------------------------------------
                 Property                             Value a
------------------------------------------------------------------------
Methane, CH4.............................  Minimum, 0.87 mol/mol.
Ethane, C2H6.............................  Maximum, 0.055 mol/mol.
Propane, C3H8............................  Maximum, 0.012 mol/mol.
Butane, C4H10............................  Maximum, 0.0035 mol/mol.
Pentane, C5H12...........................  Maximum, 0.0013 mol/mol.
C6 and higher............................  Maximum, 0.001 mol/mol.
Oxygen...................................  Maximum, 0.001 mol/mol.
Inert gases (sum of CO2 and N2)..........  Maximum, 0.051 mol/mol.
------------------------------------------------------------------------
\a\ Demonstrate compliance with fuel specifications based on the
  reference procedures in ASTM D1945 (incorporated by reference in Sec.
   1065.1010), or on other measurement procedures using good engineering
  judgment. See Sec.   1065.701(d) for other allowed procedures.

    (b) In certain cases you may use test fuel not meeting the 
specifications in paragraph (a) of this section, as follows:
    (1) You may use fuel that your in-use engines normally use, such as 
pipeline natural gas.
    (2) You may use fuel meeting alternate specifications if the 
standard-setting part allows it.

[[Page 264]]

    (3) You may ask for approval to use fuel that does not meet the 
specifications in paragraph (a) of this section, but only if using the 
fuel would not adversely affect your ability to demonstrate compliance 
with the applicable standards in this chapter.
    (c) When we conduct testing using natural gas, we will use fuel that 
meets the specifications in paragraph (a) of this section.
    (d) At ambient conditions, natural gas must have a distinctive odor 
detectable down to a concentration in air not more than one-fifth the 
lower flammable limit.

[73 FR 37342, June 30, 2008, as amended at 79 FR 23811, Apr. 28, 2014; 
86 FR 34573, June 29, 2021; 88 FR 4687, Jan. 24, 2023]



Sec.  1065.720  Liquefied petroleum gas.

    (a) Except as specified in paragraph (b) of this section, liquefied 
petroleum gas for testing must meet the specifications in the following 
table:

  Table 1 to Paragraph (a) of Sec.   1065.720--Test Fuel Specifications
                       for Liquefied Petroleum Gas
------------------------------------------------------------------------
                                                           Reference
            Property                     Value           procedure \a\
------------------------------------------------------------------------
Propane, CH.....................  Minimum, 0.85 m\3\/ ASTM D2163.
                                   m\3\.
Vapor pressure at 38 [deg]C.....  Maximum, 1400 kPa.  ASTM D1267 or
                                                      ASTM D2598 \b\.
Butanes.........................  Maximum, 0.05 m\3\/ ASTM D2163.
                                   m\3\.
Butenes.........................  Maximum, 0.02 m     ASTM D2163.
                                   \3\/m \3\.
Pentenes and heavier............  Maximum, 0.005 m    ASTM D2163.
                                   \3\/m\3\.
Propene.........................  Maximum, 0.1 m \3\/ ASTM D2163.
                                   m\3\.
Residual matter (residue on       Maximum, 0.05 ml    ASTM D2158.
 evaporation of 100 ml oil stain   pass \c\.
 observation).
Corrosion, copper strip.........  Maximum, No. 1....  ASTM D1838.
Sulfur..........................  Maximum, 80 mg/kg.  ASTM D6667.
Moisture content................  pass..............  ASTM D2713.
------------------------------------------------------------------------
\a\ Incorporated by reference; see Sec.   1065.1010. See Sec.
  1065.701(d) for other allowed procedures.
\b\ If these two test methods yield different results, use the results
  from ASTM D1267.
\c\ The test fuel must not yield a persistent oil ring when you add 0.3
  ml of solvent residue mixture to a filter paper in 0.1 ml increments
  and examine it in daylight after two minutes.

    (b) In certain cases you may use test fuel not meeting the 
specifications in paragraph (a) of this section, as follows:
    (1) You may use fuel that your in-use engines normally use, such as 
commercial-quality liquefied petroleum gas.
    (2) You may use fuel meeting alternate specifications if the 
standard-setting part allows it.
    (3) You may ask for approval to use fuel that does not meet the 
specifications in paragraph (a) of this section, but only if using the 
fuel would not adversely affect your ability to demonstrate compliance 
with the applicable standards in this chapter.
    (c) When we conduct testing using liquefied petroleum gas, we will 
use fuel that meets the specifications in paragraph (a) of this section.
    (d) At ambient conditions, liquefied petroleum gas must have a 
distinctive odor detectable down to a concentration in air not more than 
one-fifth the lower flammable limit.

[73 FR 37342, June 30, 2008, as amended at 79 FR 23811, Apr. 28, 2014; 
86 FR 34573, June 29, 2021; 88 FR 4687, Jan. 24, 2023]



Sec.  1065.725  High-level ethanol-gasoline blends.

    For testing vehicles capable of operating on a high-level ethanol-
gasoline blend, create a test fuel as follows:
    (a) Add ethanol to an E10 fuel meeting the specifications described 
in Sec.  1065.710 until the ethanol content of the blended fuel is 
between 80 and 83 volume %.
    (b) You may alternatively add ethanol to a gasoline base fuel with 
no ethanol if you can demonstrate that such a base fuel blended with the 
proper amount of ethanol would meet all the specifications for E10 test 
fuel described in Sec.  1065.710, other than the ethanol content.
    (c) The ethanol used for blending must be either denatured fuel 
ethanol

[[Page 265]]

meeting the specifications in 40 CFR 1090.270, or fuel-grade ethanol 
with no denaturant. Account for the volume of any denaturant when 
calculating volumetric percentages.
    (d) The blended test fuel must have a dry vapor pressure equivalent 
between 41.5 and 45.1 kPa (6.0 and 6.5 psi) when measured using the 
procedure specified in Sec.  1065.710. You may add commercial grade 
butane as needed to meet this specification.

[79 FR 23811, Apr. 28, 2014, as amended at 85 FR 78468, Dec. 4, 2020]



Sec.  1065.735  Diesel exhaust fluid.

    (a) Use commercially available diesel exhaust fluid that represents 
the product that will be used in your in-use engines.
    (b) Diesel exhaust fluid for testing must generally conform to the 
specifications referenced in the definition of ``diesel exhaust fluid'' 
in Sec.  1065.1001. Use marine-grade diesel exhaust fluid only for 
marine engines.

[81 FR 74191, Oct. 25, 2016]



Sec.  1065.740  Lubricants.

    (a) Use commercially available lubricating oil that represents the 
oil that will be used in your engine in use.
    (b) You may use lubrication additives, up to the levels that the 
additive manufacturer recommends.



Sec.  1065.745  Coolants.

    (a) You may use commercially available antifreeze mixtures or other 
coolants that will be used in your engine in use.
    (b) For laboratory testing of liquid-cooled engines, you may use 
water with or without rust inhibitors.
    (c) For coolants allowed in paragraphs (a) and (b) of this section, 
you may use rust inhibitors and additives required for lubricity, up to 
the levels that the additive manufacturer recommends.



Sec.  1065.750  Analytical gases.

    Analytical gases must meet the accuracy and purity specifications of 
this section, unless you can show that other specifications would not 
affect your ability to show that you comply with all applicable emission 
standards.
    (a) Subparts C, D, F, and J of this part refer to the following gas 
specifications:
    (1) Use purified gases to zero measurement instruments and to blend 
with calibration gases. Use gases with contamination no higher than the 
highest of the following values in the gas cylinder or at the outlet of 
a zero-gas generator:
    (i) 2% contamination, measured relative to the flow-weighted mean 
concentration expected at the standard. For example, if you would expect 
a flow-weighted CO concentration of 100.0 [micro]mol/mol, then you would 
be allowed to use a zero gas with CO contamination less than or equal to 
2.000 [micro]mol/mol.
    (ii) Contamination as specified in the following table:

  Table 1 of Sec.   1065.750--General Specifications for Purified Gases
                                   \a\
------------------------------------------------------------------------
          Constituent                Purified air          Purified N2
------------------------------------------------------------------------
THC (C1-equivalent)...........  <=0.05 [micro]mol/mol.  <=0.05
                                                         [micro]mol/mol.
CO............................  <=1 [micro]mol/mol....  <=1 [micro]mol/
                                                         mol.
CO2...........................  <=10 [micro]mol/mol...  <=10 [micro]mol/
                                                         mol.
O2............................  0.205 to 0.215 mol/mol  <=2 [micro]mol/
                                                         mol.
NOX...........................  <=0.02 [micro]mol/mol.  <=0.02
                                                         [micro]mol/mol.
N2O b.........................  <=0.02 [micro]mol/mol.  <=0.02
                                                         [micro]mol/mol.
------------------------------------------------------------------------
a We do not require these levels of purity to be NIST-traceable.
b The N2O limit applies only if the standard-setting part requires you
  to report N2O or certify to an N2O standard.

    (2) Use the following gases with a FID analyzer:
    (i) FID fuel. Use FID fuel with a stated H2 concentration 
of (0.39 to 0.41) mol/mol, balance He or N2, and a stated 
total hydrocarbon concentration of 0.05 [micro]mol/mol or less. For GC-
FIDs that measure methane (CH4) using a FID fuel that is 
balance N2, perform the CH4 measurement as 
described in SAE J1151 (incorporated by reference in Sec.  1065.1010).

[[Page 266]]

    (ii) FID burner air. Use FID burner air that meets the 
specifications of purified air in paragraph (a)(1) of this section. For 
field testing, you may use ambient air.
    (iii) FID zero gas. Zero flame-ionization detectors with purified 
gas that meets the specifications in paragraph (a)(1) of this section, 
except that the purified gas O2 concentration may be any 
value. Note that FID zero balance gases may be any combination of 
purified air and purified nitrogen. We recommend FID analyzer zero gases 
that contain approximately the expected flow-weighted mean concentration 
of O2 in the exhaust sample during testing.
    (iv) FID propane span gas. Span and calibrate THC FID with span 
concentrations of propane, C3H8. Calibrate on a 
carbon number basis of one (C1). For example, if you use a 
C3H8 span gas of concentration 200 [micro]mol/mol, 
span a FID to respond with a value of 600 [micro]mol/mol. Note that FID 
span balance gases may be any combination of purified air and purified 
nitrogen. We recommend FID analyzer span gases that contain 
approximately the flow-weighted mean concentration of O2 
expected during testing. If the expected O2 concentration in 
the exhaust sample is zero, we recommend using a balance gas of purified 
nitrogen.
    (v) FID CH4 span gas. If you always span and calibrate a 
CH4 FID with a nonmethane cutter, then span and calibrate the 
FID with span concentrations of CH4. Calibrate on a carbon 
number basis of one (C1). For example, if you use a 
CH4 span gas of concentration 200 [micro]mol/mol, span a FID 
to respond with a value of 200 [micro]mol/mol. Note that FID span 
balance gases may be any combination of purified air and purified 
nitrogen. We recommend FID analyzer span gases that contain 
approximately the expected flow-weighted mean concentration of 
O2 in the exhaust sample during testing. If the expected 
O2 concentration in the exhaust sample is zero, we recommend 
using a balance gas of purified nitrogen.
    (3) Use the following gas mixtures, with gases traceable within 
1% of the NIST-accepted value or other gas 
standards we approve:
    (i) CH4, balance purified air and/or N2 (as 
applicable).
    (ii) C2H6, balance purified air and/or 
N2 (as applicable).
    (iii) C3H8, balance purified air and/or 
N2 (as applicable).
    (iv) CO, balance purified N2.
    (v) CO2, balance purified N2.
    (vi) NO, balance purified N2.
    (vii) NO2, balance purified air.
    (viii) O2, balance purified N2.
    (ix) C3H8, CO, CO2, NO, balance 
purified N2.
    (x) C3H8, CH4, CO, CO2, 
NO, balance purified N2.
    (xi) N2O, balance purified air and/or N2 (as 
applicable).
    (xii) CH4, C2H6, balance purified 
air and/or N2 (as applicable).
    (xiii) CH4, CH2O, CH2O2, 
C2H2, C2H4, 
C2H4O, C2H6, 
C3H8, C3H6, CH4O, 
and C4H10. You may omit individual gas 
constituents from this gas mixture. If your gas mixture contains 
oxygenated hydrocarbon, your gas mixture must be in balance purified 
N2, otherwise you may use balance purified air.
    (4) You may use gases for species other than those listed in 
paragraph (a)(3) of this section (such as methanol in air, which you may 
use to determine response factors), as long as they are traceable to 
within 3% of the NIST-accepted value or other 
similar standards we approve, and meet the stability requirements of 
paragraph (b) of this section.
    (5) You may generate your own calibration gases using a precision 
blending device, such as a gas divider, to dilute gases with purified 
N2 or purified air. If your gas divider meets the 
specifications in Sec.  1065.248, and the gases being blended meet the 
requirements of paragraphs (a)(1) and (3) of this section, the resulting 
blends are considered to meet the requirements of this paragraph (a).
    (b) Record the concentration of any calibration gas standard and its 
expiration date specified by the gas supplier.
    (1) Do not use any calibration gas standard after its expiration 
date, except as allowed by paragraph (b)(2) of this section.
    (2) Calibration gases may be relabeled and used after their 
expiration date as follows:

[[Page 267]]

    (i) Alcohol/carbonyl calibration gases used to determine response 
factors according to subpart I of this part may be relabeled as 
specified in subpart I of this part.
    (ii) Other gases may be relabeled and used after the expiration date 
only if we approve it in advance.
    (c) Transfer gases from their source to analyzers using components 
that are dedicated to controlling and transferring only those gases. For 
example, do not use a regulator, valve, or transfer line for zero gas if 
those components were previously used to transfer a different gas 
mixture. We recommend that you label regulators, valves, and transfer 
lines to prevent contamination. Note that even small traces of a gas 
mixture in the dead volume of a regulator, valve, or transfer line can 
diffuse upstream into a high-pressure volume of gas, which would 
contaminate the entire high-pressure gas source, such as a compressed-
gas cylinder.
    (d) To maintain stability and purity of gas standards, use good 
engineering judgment and follow the gas standard supplier's 
recommendations for storing and handling zero, span, and calibration 
gases. For example, it may be necessary to store bottles of condensable 
gases in a heated environment.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37343, June 30, 2008; 
74 FR 56518, Oct. 30, 2009; 75 FR 68465, Nov. 8, 2010; 76 FR 57467, 
Sept. 15, 2011; 79 FR 23811, Apr. 28, 2014; 81 FR 74191, Oct. 25, 2016; 
86 FR 34574, June 29, 2021]



Sec.  1065.790  Mass standards.

    (a) PM balance calibration weights. Use PM balance calibration 
weights that are certified as NIST-traceable within 0.1% uncertainty. Make sure your highest calibration 
weight has no more than ten times the mass of an unused PM-sample 
medium.
    (b) Dynamometer, fuel mass scale, and DEF mass scale calibration 
weights. Use dynamometer and mass scale calibration weights that are 
certified as NIST-traceable within 0.1% 
uncertainty.

[88 FR 4687, Jan. 24, 2023]



                 Subpart I_Testing With Oxygenated Fuels



Sec.  1065.801  Applicability.

    (a) This subpart applies for testing with oxygenated fuels. Unless 
the standard-setting part specifies otherwise, the requirements of this 
subpart do not apply for fuels that contain less than 25% oxygenated 
compounds by volume. For example, you generally do not need to follow 
the requirements of this subpart for tests performed using a fuel 
containing 10% ethanol and 90% gasoline, but you must follow these 
requirements for tests performed using a fuel containing 85% ethanol and 
15% gasoline.
    (b) Section 1065.805 applies for all other testing that requires 
measurement of any alcohols or carbonyls.
    (c) This subpart specifies sampling procedures and calculations that 
are different than those used for non-oxygenated fuels. All other test 
procedures of this part 1065 apply for testing with oxygenated fuels.



Sec.  1065.805  Sampling system.

    (a) Dilute engine exhaust, and use batch sampling to collect 
proportional flow-weighted dilute samples of the applicable alcohols and 
carbonyls. You may not use raw sampling for alcohols and carbonyls.
    (b) You may collect background samples for correcting dilution air 
for background concentrations of alcohols and carbonyls.
    (c) Maintain sample temperatures within the dilution tunnel, probes, 
and sample lines high enough to prevent aqueous condensation up to the 
point where a sample is collected to prevent loss of the alcohols and 
carbonyls by dissolution in condensed water. Use good engineering 
judgment to ensure that surface reactions of alcohols and carbonyls do 
not occur, as surface decomposition of methanol has been shown to occur 
at temperatures greater than 120 [deg]C in exhaust from methanol-fueled 
engines.
    (d) You may bubble a sample of the exhaust through water to collect 
alcohols for later analysis. You may also use a photoacoustic analyzer 
to quantify ethanol and methanol in an exhaust sample as described in 
Sec.  1065.269.

[[Page 268]]

    (e) Sample the exhaust through cartridges impregnated with 2,4-
dinitrophenylhydrazine to collect carbonyls for later analysis. If the 
standard-setting part specifies a duty cycle that has multiple test 
intervals (such as multiple engine starts or an engine-off soak phase), 
you may proportionally collect a single carbonyl sample for the entire 
duty cycle. For example, if the standard-setting part specifies a six-
to-one weighting of hot-start to cold-start emissions, you may collect a 
single carbonyl sample for the entire duty cycle by using a hot-start 
sample flow rate that is six times the cold-start sample flow rate.
    (f) You may sample alcohols or carbonyls using ``California Non-
Methane Organic Gas Test Procedures'' (incorporated by reference in 
Sec.  1065.1010). If you use this method, follow its calculations to 
determine the mass of the alcohol/carbonyl in the exhaust sample, but 
follow subpart G of this part for all other calculations (40 CFR part 
1066, subpart G, for vehicle testing).
    (g) Use good engineering judgment to sample other oxygenated 
hydrocarbon compounds in the exhaust.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37343, June 30, 2008; 
79 FR 23812, Apr. 28, 2014]



Sec.  1065.845  Response factor determination.

    Since FID analyzers generally have an incomplete response to 
alcohols and carbonyls, determine each FID analyzer's alcohol/carbonyl 
response factor (RFOHCi[THC-FID]) after FID optimization to 
subtract those responses from the FID reading. Use the most recently 
determined alcohol/carbonyl response factors to compensate for alcohol/
carbonyl response. You are not required to determine the response factor 
for a compound unless you will subtract its response to compensate for a 
response.
    (a) You may generate response factors as described in paragraph (b) 
of this section, or you may use the following default response factors, 
consistent with good engineering judgment:

 Table 1 of Sec.   1065.845--Default Values for THC FID Response Factor
              Relative to Propane on a C1-Equivalent Basis
------------------------------------------------------------------------
                                                         Response factor
                        Compound                               (RF)
------------------------------------------------------------------------
acetaldehyde...........................................             0.50
ethanol................................................             0.75
formaldehyde...........................................             0.00
methanol...............................................             0.63
propanol...............................................             0.85
------------------------------------------------------------------------

    (b) Determine the alcohol/carbonyl response factors as follows:
    (1) Select a C3H8 span gas that meets the 
specifications of Sec.  1065.750. Note that FID zero and span balance 
gases may be any combination of purified air or purified nitrogen that 
meets the specifications of Sec.  1065.750. We recommend FID analyzer 
zero and span gases that contain approximately the flow-weighted mean 
concentration of O2 expected during testing. Record the 
C3H8 concentration of the gas.
    (2) Select or prepare an alcohol/carbonyl calibration gas that meets 
the specifications of Sec.  1065.750 and has a concentration typical of 
the peak concentration expected at the hydrocarbon standard. Record the 
calibration concentration of the gas.
    (3) Start and operate the FID analyzer according to the 
manufacturer's instructions.
    (4) Confirm that the FID analyzer has been calibrated using 
C3H8. Calibrate on a carbon number basis of one 
(C1). For example, if you use a C3H8 
span gas of concentration 200 [micro]mol/mol, span the FID to respond 
with a value of 600 [micro]mol/mol.
    (5) Zero the FID. Note that FID zero and span balance gases may be 
any combination of purified air or purified nitrogen that meets the 
specifications of Sec.  1065.750. We recommend FID analyzer zero and 
span gases that contain approximately the flow-weighted mean 
concentration of O2 expected during testing.
    (6) Span the FID with the C3H8 span gas that 
you selected under paragraph (a)(1) of this section.
    (7) Introduce at the inlet of the FID analyzer the alcohol/carbonyl 
calibration gas that you selected under paragraph (a)(2) of this 
section.
    (8) Allow time for the analyzer response to stabilize. Stabilization 
time

[[Page 269]]

may include time to purge the analyzer and to account for its response.
    (9) While the analyzer measures the alcohol/carbonyl concentration, 
record 30 seconds of sampled data. Calculate the arithmetic mean of 
these values.
    (10) Divide the mean measured concentration by the recorded span 
concentration of the alcohol/carbonyl calibration gas on a 
C1-equivalent basis. The result is the FID analyzer's 
response factor for alcohol/carbonyl, RFOHCi[THC-FID] on a 
C1-equivalent basis.
    (c) Alcohol/carbonyl calibration gases must remain within 2% of the labeled concentration. You must demonstrate 
the stability based on a quarterly measurement procedure with a 
precision of 2% percent or another method that we 
approve. Your measurement procedure may incorporate multiple 
measurements. If the true concentration of the gas changes deviates by 
more than 2%, but less than 10%, the gas may be relabeled with the new 
concentration.

[79 FR 23812, Apr. 28, 2014, as amended at 79 FR 36658, June 30, 2014]



Sec.  1065.850  Calculations.

    Use the calculations specified in Sec.  1065.665 to determine THCE 
or NMHCE and the calculations specified in 40 CFR 1066.635 to determine 
NMOG.

[79 FR 23813, Apr. 28, 2014]



    Subpart J_Field Testing and Portable Emission Measurement Systems



Sec.  1065.901  Applicability.

    (a) Field testing. This subpart specifies procedures for field-
testing engines to determine brake-specific emissions and mass rate 
emissions using portable emission measurement systems (PEMS). These 
procedures are designed primarily for in-field measurements of engines 
that remain installed in vehicles or equipment the field. Field-test 
procedures apply to your engines only as specified in the standard-
setting part.
    (b) Laboratory testing. You may use PEMS for any testing in a 
laboratory or similar environment without restriction or prior approval 
if the PEMS meets all applicable specifications for laboratory testing. 
You may also use PEMS for any testing in a laboratory or similar 
environment if we approve it in advance, subject to the following 
provisions:
    (1) Follow the laboratory test procedures specified in this part 
1065, according to Sec.  1065.905(e).
    (2) Do not apply any PEMS-related field-testing adjustments or 
measurement allowances to laboratory emission results or standards.
    (3) Do not use PEMS for laboratory measurements if it prevents you 
from demonstrating compliance with the applicable standards in this 
chapter. Some of the PEMS requirements in this part 1065 are less 
stringent than the corresponding laboratory requirements. Depending on 
actual PEMS performance, you might therefore need to account for some 
additional measurement uncertainty when using PEMS for laboratory 
testing. If we ask, you must show us by engineering analysis that any 
additional measurement uncertainty due to your use of PEMS for 
laboratory testing is offset by the extent to which your engine's 
emissions are below the applicable standards in this chapter. For 
example, you might show that PEMS versus laboratory uncertainty 
represents 5% of the standard, but your engine's deteriorated emissions 
are at least 20% below the standard for each pollutant.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37344, June 30, 2008; 
88 FR 4687, Jan. 24, 2023]



Sec.  1065.905  General provisions.

    (a) General. Unless the standard-setting part specifies deviations 
from the provisions of this subpart, field testing and laboratory 
testing with PEMS must conform to the provisions of this subpart. Use 
good engineering judgment when testing with PEMS to ensure proper 
function of the instruments under test conditions. For example, this may 
require additional maintenance or calibration for field testing or may 
require verification after moving the PEMS unit.
    (b) Field-testing scope. Field testing conducted under this subpart 
may include any normal in-use operation of an engine.

[[Page 270]]

    (c) Field testing and the standard-setting part. This subpart J 
specifies procedures for field-testing various categories of engines. 
See the standard-setting part for specific provisions for a particular 
type of engine. Before using this subpart's procedures for field 
testing, read the standard-setting part to answer at least the following 
questions:
    (1) How many engines must I test in the field?
    (2) How many times must I repeat a field test on an individual 
engine?
    (3) How do I select vehicles for field testing?
    (4) What maintenance steps may I take before or between tests?
    (5) What data are needed for a single field test on an individual 
engine?
    (6) What are the limits on ambient conditions for field testing? 
Note that the ambient condition limits in Sec.  1065.520 do not apply 
for field testing. Field testing may occur at any ambient temperature, 
pressure, and humidity unless otherwise specified in the standard-
setting part.
    (7) Which exhaust constituents do I need to measure?
    (8) How do I account for crankcase emissions?
    (9) Which engine and ambient parameters do I need to measure?
    (10) How do I process the data recorded during field testing to 
determine if my engine meets field-testing standards? How do I determine 
individual test intervals? Note that ``test interval'' is defined in 
subpart K of this part 1065.
    (11) Should I warm up the test engine before measuring emissions, or 
do I need to measure cold-start emissions during a warm-up segment of 
in-use operation?
    (12) Do any unique specifications apply for test fuels?
    (13) Do any special conditions invalidate parts of a field test or 
all of a field test?
    (14) Does any special measurement allowance apply to field-test 
emission results or standards, based on using PEMS for field-testing 
versus using laboratory equipment and instruments for laboratory 
testing?
    (15) Do results of initial field testing trigger any requirement for 
additional field testing or laboratory testing?
    (16) How do I report field-testing results?
    (d) Field testing and this part 1065. Use the following 
specifications for field testing:
    (1) Use the applicability and general provisions of subpart A of 
this part.
    (2) Use equipment specifications in Sec.  1065.101 and in the 
sections from Sec.  1065.140 to the end of subpart B of this part, with 
the exception of Sec. Sec.  1065.140(e)(1) and (4), 1065.170(c)(1)(vi), 
and 1065.195(c). Section 1065.910 identifies additional equipment that 
is specific to field testing.
    (i) For PM samples, configure dilution systems as follows:
    (A) Use good engineering judgment to control dilution air 
temperature. If you choose to directly and actively control dilution air 
temperature, set the temperature to 25 [deg]C.
    (B) Control sample temperature to a (32 to 62) [deg]C tolerance, as 
measured anywhere within 20 cm upstream or downstream of the PM storage 
media (such as a filter or oscillating crystal), where the tolerance 
applies only during sampling.
    (C) Maintain filter face velocity to a (5 to 100) cm/s tolerance for 
flow-through media. Compliance with this provision can be verified by 
engineering analysis. This provision does not apply for non-flow-through 
media.
    (ii) For inertial PM balances, there is no requirement to control 
the stabilization environment temperature or dewpoint.
    (3) Use measurement instruments in subpart C of this part, except as 
specified in Sec.  1065.915.
    (4) Use calibrations and verifications in subpart D of this part, 
except as specified in Sec.  1065.920. Section 1065.920 also specifies 
additional calibrations and verifications for field testing.
    (5) Use the provisions of the standard-setting part for selecting 
and maintaining engines in the field instead of the specifications in 
subpart E of this part.
    (6) Use the procedures in Sec. Sec.  1065.930 and 1065.935 to start 
and run a field test. If you use a gravimetric balance

[[Page 271]]

for PM, weigh PM samples according to Sec. Sec.  1065.590 and 1065.595.
    (7) Use the calculations in subpart G of this part to calculate 
emissions over each test interval. Note that ``test interval'' is 
defined in subpart K of this part 1065, and that the standard setting 
part indicates how to determine test intervals for your engine.
    Section 1065.940 specifies additional calculations for field 
testing. Use any calculations specified in the standard-setting part to 
determine if your engines meet the field-testing standards. The 
standard-setting part may also contain additional calculations that 
determine when further field testing is required.
    (8) Use a typical in-use fuel meeting the specifications of Sec.  
1065.701(d).
    (9) Use the lubricant and coolant specifications in Sec. Sec.  
1065.740 and 1065.745.
    (10) Use the analytical gases and other calibration standards in 
Sec.  1065.750 and Sec.  1065.790.
    (11) If you are testing with oxygenated fuels, use the procedures 
specified for testing with oxygenated fuels in subpart I of this part.
    (12) Apply the definitions and reference materials in subpart K of 
this part.
    (e) Laboratory testing using PEMS. You may use PEMS for testing in a 
laboratory as described in Sec.  1065.901(b). Use the following 
procedures and specifications when using PEMS for laboratory testing:
    (1) Use the applicability and general provisions of subpart A of 
this part.
    (2) Use equipment specifications in subpart B of this part. Section 
1065.910 specifies additional equipment specific to testing with PEMS.
    (3) Use measurement instruments in subpart C of this part, except as 
specified in Sec.  1065.915.
    (4) Use calibrations and verifications in subpart D of this part, 
except as specified in Sec.  1065.920. Section 1065.920 also specifies 
additional calibration and verifications for PEMS.
    (5) Use the provisions of Sec.  1065.401 for selecting engines for 
testing. Use the provisions of subpart E of this part for maintaining 
engines, except as specified in the standard-setting part.
    (6) Use the procedures in subpart F of this part and in the 
standard-setting part to start and run a laboratory test.
    (7) Use the calculations in subpart G of this part to calculate 
emissions over the applicable duty cycle. Section 1065.940 specifies 
additional calculations for testing with PEMS.
    (8) Use a fuel meeting the specifications of subpart H of this part, 
as specified in the standard-setting part.
    (9) Use the lubricant and coolant specifications in Sec. Sec.  
1065.740 and 1065.745.
    (10) Use the analytical gases and other calibration standards in 
Sec. Sec.  1065.750 and 1065.790.
    (11) If you are testing with oxygenated fuels, use the procedures 
specified for testing with oxygenated fuels in subpart I of this part.
    (12) Apply the definitions and reference materials in subpart K of 
this part.
    (f) Summary. The following table summarizes the requirements of 
paragraphs (d) and (e) of this section:

          Table 1 of Sec.   1065.905--Summary of Testing Requirements Specified Outside of This Subpart
----------------------------------------------------------------------------------------------------------------
                                                                     Applicability for
                                                                   laboratory or similar     Applicability for
              Subpart                  Applicability for field       testing with PEMS     laboratory or similar
                                              testing a            without restriction a  testing with PEMS with
                                                                                              restrictions a
----------------------------------------------------------------------------------------------------------------
A: Applicability and general         Use all....................  Use all...............  Use all.
 provisions.
B: Equipment for testing...........  Use Sec.  Sec.   1065.101    Use all...............  Use all. Section
                                      and 1065.140 through the                             1065.910 specifies
                                      end of subpart B of this                             equipment specific to
                                      part, except Sec.  Sec.                              laboratory testing
                                      1065.140(e)(1) and (4),                              with PEMS.
                                      1065.170(c)(1)(vi), and
                                      1065.195(c). Section
                                      1065.910 specifies
                                      equipment specific to
                                      field testing.
C: Measurement instruments.........  Use all Section 1065.915     Use all except Sec.     Use all except Sec.
                                      allows deviations..          1065.295(c).            1065.295(c).
                                                                                          Section1065.915 allows
                                                                                           deviations.

[[Page 272]]

 
D: Calibrations and verifications..  Use all except Sec.  Sec.    Use all...............  Use all. Section
                                      1065.308 and 1065.309.                               1065.920 allows
                                      Section 1065.920 allows                              deviations, but also
                                      deviations, but also has                             has additional
                                      additional specifications.                           specifications.
E: Test engine selection,            Do not use Use standard-     Use all...............  Use all.
 maintenance, and durability.         setting part..
F: Running an emission test in the   Use Sec.  Sec.   1065.590    Use all...............  Use all.
 laboratory.                          and 1065.595 for PM. Sec.
                                      Sec.   1065.930 and
                                      1065.935 to start and run
                                      a field test.
G: Calculations and data             Use all Section 1065.940     Use all...............  Use all. Section
 requirements.                        has additional calculation                           1065.940 has
                                      instructions.                                        additional
                                                                                           calculation
                                                                                           instructions
H: Fuels, engine fluids, analytical  Use all....................  Use all...............  Use all.
 gases, and other calibration
 materials.
I: Testing with oxygenated fuels...  Use all....................  Use all...............  Use all.
K: Definitions and reference         Use all....................  Use all...............  Use all.
 materials.
----------------------------------------------------------------------------------------------------------------
a Refer to paragraphs (d) and (e) of this section for complete specifications.


[70 FR 40516, July 13, 2005, as amended at 73 FR 37344, June 30, 2008; 
75 FR 68465, Nov. 8, 2010; 79 FR 23813, Apr. 28, 2014; 86 FR 34574, June 
29, 2021]



Sec.  1065.910  PEMS auxiliary equipment for field testing.

    For field testing you may use various types of auxiliary equipment 
to attach PEMS to a vehicle or engine and to power PEMS.
    (a) When you use PEMS, you may route engine intake air or exhaust 
through a flow meter. Route the engine intake air or exhaust as follows:
    (1) Flexible connections. Use short flexible connectors where 
necessary.
    (i) You may use flexible connectors to enlarge or reduce the pipe 
diameters to match that of your test equipment.
    (ii) We recommend that you use flexible connectors that do not 
exceed a length of three times their largest inside diameter.
    (iii) We recommend that you use four-ply silicone-fiberglass fabric 
with a temperature rating of at least 315 [deg]C for flexible 
connectors. You may use connectors with a spring-steel wire helix for 
support and you may use Nomex \TM\ coverings or linings for durability. 
You may also use any other nonreactive material with equivalent 
permeation-resistance and durability, as long as it seals tightly.
    (iv) Use stainless-steel hose clamps to seal flexible connectors, or 
use clamps that seal equivalently.
    (v) You may use additional flexible connectors to connect to flow 
meters.
    (2) Tubing. We recommend using rigid 300 series stainless steel 
tubing to connect between flexible connectors. Tubing may be straight or 
bent to accommodate vehicle geometry. You may use ``T'' or ``Y'' 
fittings to join multiple connections, or you may cap or plug redundant 
flow paths if the engine manufacturer recommends it.
    (3) Flow restriction. Use flow meters, connectors, and tubing that 
do not increase flow restriction so much that it exceeds the 
manufacturer's maximum specified value. You may verify this at the 
maximum exhaust flow rate by measuring pressure at the manufacturer-
specified location with your system connected. You may also perform an 
engineering analysis to verify an acceptable configuration, taking into 
account the maximum exhaust flow rate

[[Page 273]]

expected, the field test system's flexible connectors, and the tubing's 
characteristics for pressure drops versus flow.
    (b) Locate the PEMS to minimize the effects of the following 
parameters or place the PEMS in an environmental enclosure that 
minimizes the effect of these parameters on the emission measurement:
    (1) Ambient temperature changes.
    (2) Electromagnetic radiation.
    (3) Mechanical shock and vibration.
    (c) Use mounting hardware as required for securing flexible 
connectors, ambient sensors, and other equipment. Use structurally sound 
mounting points such as vehicle frames, trailer hitch receivers, walk 
spaces, and payload tie-down fittings. We recommend mounting hardware 
such as clamps, suction cups, and magnets that are specifically designed 
for your application. We also recommend considering mounting hardware 
such as commercially available bicycle racks, trailer hitches, and 
luggage racks where applicable.
    (d) Field testing may require portable electrical power to run your 
test equipment. Power your equipment, as follows:
    (1) You may use electrical power from the vehicle, equipment, or 
vessel, up to the highest power level, such that all the following are 
true:
    (i) The power system is capable of safely supplying power, such that 
the power demand for testing does not overload the power system.
    (ii) The engine emissions do not change significantly as a result of 
the power demand for testing.
    (iii) The power demand for testing does not increase output from the 
engine by more than 1% of its maximum power.
    (2) You may install your own portable power supply. For example, you 
may use batteries, fuel cells, a portable generator, or any other power 
supply to supplement or replace your use of vehicle power. You may 
connect an external power source directly to the vehicle's, vessel's, or 
equipment's power system; however, you must not supply power to the 
vehicle's power system in excess of 1% of the engine's maximum power.

[73 FR 37344, June 30, 2008, as amended at 75 FR 23058, Apr. 30, 2010; 
86 FR 34575, June 29, 2021; 88 FR 4688, Jan. 24, 2023]



Sec.  1065.915  PEMS instruments.

    (a) Instrument specifications. We recommend that you use PEMS that 
meet the specifications of subpart C of this part. For unrestricted use 
of PEMS in a laboratory or similar environment, use a PEMS that meets 
the same specifications as each lab instrument it replaces. For field 
testing or for testing with PEMS in a laboratory or similar environment, 
under the provisions of Sec.  1065.905(b), the specifications in the 
following table apply instead of the specifications in Table 1 of Sec.  
1065.205:

             Table 1 of Sec.   1065.915--Recommended Minimum PEMS Measurement Instrument Performance
----------------------------------------------------------------------------------------------------------------
                                            Rise time,
                                Measured   t10-90, and   Recording
         Measurement            quantity    Fall time,    update       Accuracy a    Repeatability a    Noise a
                                 symbol       t90-10     frequency
 
----------------------------------------------------------------------------------------------------------------
Engine speed transducer......  fn........  1 s........  1 Hz means  5% of pt. or 1%  2% of pt. or 1%  0.5% of
                                                                     of max.          of max.          max.
Engine torque estimator, BSFC  T or BSFC.  1 s........  1 Hz means  8% of pt. or 5%  2% of pt. or 1%  1% of max.
 (This is a signal from an                                           of max.          of max.
 engine's ECM).
General pressure transducer    p.........  5 s........  1 Hz......  5% of pt. or 5%  2% of pt. or     1% of max.
 (not a part of another                                              of max.          0.5% of max.
 instrument).
Atmospheric pressure meter...  patmos....  50 s.......  0.1 Hz....  250 Pa.........  200 Pa.........  100 Pa.
General temperature sensor     T.........  5 s........  1 Hz......  1% of pt. K or   0.5% of pt. K    0.5% of
 (not a part of another                                              5 K.             or 2 K.          max 0.5
 instrument).                                                                                          K.
General dewpoint sensor......  Tdew......  50 s.......  0.1 Hz....  3 K............  1 K............  1 K.
Exhaust flow meter...........  n.........  1 s........  1 Hz means  5% of pt. or 3%  2% of pt.......  2% of max.
                                                                     of max.
Dilution air, inlet air,       n.........  1 s........  1 Hz means  2.5% of pt. or   1.25% of pt. or  1% of max.
 exhaust, and sample flow                                            1.5% of max.     0.75% of max.
 meters.

[[Page 274]]

 
Continuous gas analyzer......  x.........  5 s........  1 Hz......  4% of pt. or 4%  2% of pt. or 2%  1% of max.
                                                                     of meas.         of meas.
Gravimetric PM balance.......  mPM.......  ...........  ..........  See Sec.         0.5 [micro]g...
                                                                     1065.790.
Inertial PM balance..........  mPM.......  ...........  ..........  4% of pt. or 4%  2% of pt. or 2%  1% of max.
                                                                     of meas.         of meas.
----------------------------------------------------------------------------------------------------------------
a Accuracy, repeatability, and noise are all determined with the same collected data, as described in Sec.
  1065.305, and based on absolute values. ``pt.'' refers to the overall flow-weighted mean value expected at the
  standard; ``max.'' refers to the peak value expected at the standard over any test interval, not the maximum
  of the instrument's range; ``meas'' refers to the actual flow-weighted mean measured over any test interval.

    (b) Redundant measurements. For all PEMS described in this subpart, 
you may use data from multiple instruments to calculate test results for 
a single test. If you use redundant systems, use good engineering 
judgment to use multiple measured values in calculations or to disregard 
individual measurements. Note that you must keep your results from all 
measurements, as described in Sec.  1065.25. This requirement applies 
whether or not you actually use the measurements in your calculations.
    (c) Field-testing ambient effects on PEMS. We recommend that you use 
PEMS that are only minimally affected by ambient conditions such as 
temperature, pressure, humidity, physical orientation, mechanical shock 
and vibration, electromagnetic radiation, and ambient hydrocarbons. 
Follow the PEMS manufacturer's instructions for proper installation to 
isolate PEMS from ambient conditions that affect their performance. If a 
PEMS is inherently affected by ambient conditions that you cannot 
control, you may monitor those conditions and adjust the PEMS signals to 
compensate for the ambient effect. The standard-setting part may also 
specify the use of one or more field-testing adjustments or measurement 
allowances that you apply to results or standards to account for ambient 
effects on PEMS.
    (d) ECM signals. You may use signals from the engine's electronic 
control module (ECM) in place of values measured by individual 
instruments within a PEMS, subject to the following provisions:
    (1) Recording ECM signals. If your ECM updates a broadcast signal 
more or less frequently than 1 Hz, process data as follows:
    (i) If your ECM updates a broadcast signal more frequently than 1 
Hz, use PEMS to sample and record the signal's value more frequently. 
Calculate and record the 1 Hz mean of the more frequently updated data.
    (ii) If your ECM updates a broadcast signal less frequently than 1 
Hz, use PEMS to sample and record the signal's value at the most 
frequent rate. Linearly interpolate between recorded values and record 
the interpolated values at 1 Hz.
    (iii) Optionally, you may use PEMS to electronically filter the ECM 
signals to meet the rise time and fall time specifications in Table 1 of 
this section. Record the filtered signal at 1 Hz.
    (2) Omitting ECM signals. Replace any discontinuous or irrational 
ECM data with linearly interpolated values from adjacent data.
    (3) Aligning ECM signals with other data. You must perform time-
alignment and dispersion of ECM signals, according to PEMS manufacturer 
instructions and using good engineering judgment.
    (4) ECM signals for determining test intervals. You may use any 
combination of ECM signals, with or without other measurements, to 
determine the start-time and end-time of a test interval.
    (5) ECM signals for determining brake-specific emissions. You may 
use any combination of ECM signals, with or without other measurements, 
to estimate engine speed, torque, brake-specific fuel consumption (BSFC, 
in units

[[Page 275]]

of mass of fuel per kW-hr), and fuel rate for use in brake-specific 
emission calculations. We recommend that the overall performance of any 
speed, torque, or BSFC estimator should meet the performance 
specifications in Table 1 of this section. We recommend using one of the 
following methods:
    (i) Speed. Use the engine speed signal directly from the ECM. This 
signal is generally accurate and precise. You may develop your own speed 
algorithm based on other ECM signals.
    (ii) Torque. Use one of the following:
    (A) ECM torque. Use the engine-torque signal directly from the ECM, 
if broadcast. Determine if this signal is proportional to indicated 
torque or brake torque. If it is proportional to indicated torque, 
subtract friction torque from indicated torque and record the result as 
brake torque. Friction torque may be a separate signal broadcast from 
the ECM or you may have to determine it from laboratory data as a 
function of engine speed.
    (B) ECM %-load. Use the %-load signal directly from the ECM, if 
broadcast. Determine if this signal is proportional to indicated torque 
or brake torque. If it is proportional to indicated torque, subtract the 
minimum %-load value from the %-load signal. Multiply this result by the 
maximum brake torque at the corresponding engine speed. Maximum brake 
torque versus speed information is commonly published by the engine 
manufacturer.
    (C) Your algorithms. You may develop and use your own combination of 
ECM signals to determine torque.
    (iii) BSFC. Use one of the following:
    (A) Use ECM engine speed and ECM fuel flow signals to interpolate 
brake-specific fuel consumption data, which might be available from an 
engine laboratory as a function of ECM engine speed and ECM fuel 
signals.
    (B) Use a single BSFC value that approximates the BSFC value over a 
test interval (as defined in subpart K of this part). This value may be 
a nominal BSFC value for all engine operation determined over one or 
more laboratory duty cycles, or it may be any other BSFC that you 
determine. If you use a nominal BSFC, we recommend that you select a 
value based on the BSFC measured over laboratory duty cycles that best 
represent the range of engine operation that defines a test interval for 
field-testing. You may use the methods of this paragraph (d)(5)(iii)(B) 
only if it does not adversely affect your ability to demonstrate 
compliance with applicable standards.
    (C) You may develop and use your own combination of ECM signals to 
determine BSFC.
    (iv) ECM fuel rate. Use the fuel rate signal directly from the ECM 
and chemical balance to determine the molar flow rate of exhaust. Use 
Sec.  1065.655(d) to determine the carbon mass fraction of fuel. You may 
alternatively develop and use your own combination of ECM signals to 
determine fuel mass flow rate.
    (v) Other ECM signals. You may ask to use other ECM signals for 
determining brake-specific emissions, such as ECM air flow. We must 
approve the use of such signals in advance.
    (6) Permissible deviations. ECM signals may deviate from the 
specifications of this part 1065, but the expected deviation must not 
prevent you from demonstrating that you meet the applicable standards in 
this chapter. For example, your emission results may be sufficiently 
below an applicable standard, such that the deviation would not 
significantly change the result. As another example, a very low engine-
coolant temperature may define a logical statement that determines when 
a test interval may start. In this case, even if the ECM's sensor for 
detecting coolant temperature was not very accurate or repeatable, its 
output would never deviate so far as to significantly affect when a test 
interval may start.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37344, June 30, 2008; 
73 FR 59342, Oct. 8, 2008; 75 FR 68466, Nov. 8, 2010; 76 FR 57467, Sept. 
15, 2011; 79 FR 23813, Apr. 28, 2014; 86 FR 34575, June 29, 2021; 88 FR 
4688, Jan. 24, 2023]



Sec.  1065.920  PEMS calibrations and verifications.

    (a) Subsystem calibrations and verifications. Use all the applicable 
calibrations and verifications in subpart D of this part, including the 
linearity verifications in Sec.  1065.307, to calibrate and verify PEMS. 
Note that a PEMS does not have to meet the system-response and updating-
recording

[[Page 276]]

verifications of Sec.  1065.308 and Sec.  1065.309 if it meets the 
overall verification described in paragraph (b) of this section or if it 
measures PM using any method other than that described in Sec.  
1065.170(c)(1). This section does not apply to ECM signals. Note that 
because the regulations of this part require you to use good engineering 
judgment, it may be necessary to perform additional verifications and 
analysis. It may also be necessary to limit the range of conditions 
under which the PEMS can be used or to include specific additional 
maintenance to ensure that it functions properly under the test 
conditions. As provided in 40 CFR 1068.5, we will deem your system to 
not meet the requirements of this section if we determine that you did 
not use good engineering judgment to verify the measurement equipment. 
We may also deem your system to meet these requirements only under 
certain test conditions. If we ask for it, you must send us a summary of 
your verifications. We may also ask you to provide additional 
information or analysis to support your conclusions.
    (b) Overall verification. This paragraph (b) specifies methods and 
criteria for verifying the overall performance of systems not fully 
compliant with requirements that apply for laboratory testing. Maintain 
records to show that the particular make, model, and configuration of 
your PEMS meets this verification. You may rely on data and other 
information from the PEMS manufacturer. However, we recommend that you 
generate your own records to show that your specific PEMS meets this 
verification. If you upgrade or change the configuration of your PEMS, 
your record must show that your new configuration meets this 
verification. The verification required by this section consists of 
operating an engine over a duty cycle in the laboratory and 
statistically comparing data generated and recorded by the PEMS with 
data simultaneously generated and recorded by laboratory equipment as 
follows:
    (1) Mount an engine on a dynamometer for laboratory testing. Prepare 
the laboratory and PEMS for emission testing, as described in this part, 
to get simultaneous measurements. We recommend selecting an engine with 
emission levels close to the applicable duty-cycle standards, if 
possible.
    (2) Select or create a duty cycle that has all the following 
characteristics:
    (i) Engine operation that represents normal in-use speeds, loads, 
and degree of transient activity. Consider using data from previous 
field tests to generate a cycle.
    (ii) A duration of (6 to 9) hours.
    (3) Starting with a warmed-up engine, run a valid emission test with 
the duty cycle from paragraph (b)(2) of this section. The laboratory and 
PEMS must both meet applicable validation requirements, such as drift 
validation, hydrocarbon contamination validation, and proportional 
validation.
    (4) Determine the brake-specific emissions and mass rate emissions, 
as applicable, for each test interval for both laboratory and the PEMS 
measurements, as follows:
    (i) For both laboratory and PEMS measurements, use identical values 
to determine the beginning and end of each test interval.
    (ii) For both laboratory and PEMS measurements, use identical values 
to determine total work over each test interval.
    (iii) If the standard-setting part specifies the use of a 
measurement allowance for field testing, also apply the measurement 
allowance during calibration using good engineering judgment. If the 
measurement allowance is normally added to the standard, this means you 
must subtract the measurement allowance from measured PEMS emission 
results.
    (iv) Round results to the same number of significant digits as the 
standard.
    (5) For each test interval and emission, subtract the lab result 
from the PEMS result.
    (6) The PEMS passes the verification of this paragraph (b) if any 
one of the following are true for each constituent:
    (i) 91% or more of the differences are zero or less than zero.

[[Page 277]]

    (ii) The entire set of test-interval results passes the 95% 
confidence alternate-procedure statistics for field testing (t-test and 
F-test) specified in Sec.  1065.12.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37345, June 30, 2008; 
75 FR 68467, Nov. 8, 2010; 79 FR 23814, Apr. 28, 2014; 88 FR 4688, Jan. 
24, 2023]



Sec.  1065.925  PEMS preparation for field testing.

    Take the following steps to prepare PEMS for field testing:
    (a) Verify that ambient conditions at the start of the test are 
within the limits specified in the standard-setting part. Continue to 
monitor these values to determine if ambient conditions exceed the 
limits during the test.
    (b) Install a PEMS and any accessories needed to conduct a field 
test.
    (c) Power the PEMS and allow pressures, temperatures, and flows to 
stabilize to their operating set points.
    (d) Bypass or purge any gaseous sampling PEMS instruments with 
ambient air until sampling begins to prevent system contamination from 
excessive cold-start emissions.
    (e) Conduct calibrations and verifications.
    (f) Operate any PEMS dilution systems at their expected flow rates 
using a bypass.
    (g) If you use a gravimetric balance to determine whether an engine 
meets an applicable PM standard, follow the procedures for PM sample 
preconditioning and tare weighing as described in Sec.  1065.590. 
Operate the PM-sampling system at its expected flow rates using a 
bypass.
    (h) Verify the amount of contamination in the PEMS HC sampling 
system before the start of the field test as follows:
    (1) Select the HC analyzer range for measuring the maximum 
concentration expected at the HC standard.
    (2) Zero the HC analyzers using a zero gas or ambient air introduced 
at the analyzer port. When zeroing a FID, use the FID's burner air that 
would be used for in-use measurements (generally either ambient air or a 
portable source of burner air).
    (3) Span the HC analyzer using span gas introduced at the analyzer 
port.
    (4) Overflow zero or ambient air at the HC probe inlet or into a tee 
near the probe outlet.
    (5) Measure the HC concentration in the sampling system:
    (i) For continuous sampling, record the mean HC concentration as 
overflow zero air flows.
    (ii) For batch sampling, fill the sample medium and record its mean 
concentration.
    (6) Record this value as the initial HC concentration, 
xTHCinit, and use it to correct measured values as described 
in Sec.  1065.660.
    (7) If the initial HC concentration exceeds the greater of the 
following values, determine the source of the contamination and take 
corrective action, such as purging the system or replacing contaminated 
portions:
    (i) 2% of the flow-weighted mean concentration expected at the 
standard or measured during testing.
    (ii) 2 [micro]mol/mol.
    (8) If corrective action does not resolve the deficiency, you may 
use a contaminated HC system if it does not prevent you from 
demonstrating compliance with the applicable emission standards.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37345, June 30, 2008; 
73 FR 59342, Oct. 8, 2008; 75 FR 68467, Nov. 8, 2010; 76 FR 57467, Sept. 
15, 2011]



Sec.  1065.930  Engine starting, restarting, and shutdown.

    Unless the standard-setting part specifies otherwise, start, 
restart, and shut down the test engine for field testing as follows:
    (a) Start or restart the engine as described in the owners manual.
    (b) If the engine does not start after 15 seconds of cranking, stop 
cranking and determine the reason it failed to start. However, you may 
crank the engine longer than 15 seconds, as long as the owners manual or 
the service-repair manual describes the longer cranking time as normal.
    (c) Respond to engine stalling with the following steps:
    (1) If the engine stalls during a required warm-up before emission 
sampling begins, restart the engine and continue warm-up.

[[Page 278]]

    (2) If the engine stalls at any other time after emission sampling 
begins, restart the engine and continue testing.
    (d) Shut down and restart the engine according to the manufacturer's 
specifications, as needed during normal operation in-use, but continue 
emission sampling until the field test is complete.



Sec.  1065.935  Emission test sequence for field testing.

    (a) Time the start of field testing as follows:
    (1) If the standard-setting part requires only hot-stabilized 
emission measurements, operate the engine in-use until the engine 
coolant, block, or head absolute temperature is within 10% of its mean value for the previous 2 min or until an 
engine thermostat controls engine temperature with coolant or air flow.
    (2) If the standard-setting part requires hot-start emission 
measurements, shut down the engine after at least 2 min at the 
temperature tolerance specified in paragraph (a)(1) of this section. 
Start the field test within 20 min of engine shutdown.
    (3) If the standard-setting part requires cold-start emission 
measurements, proceed to the steps specified in paragraph (b) of this 
section.
    (b) Take the following steps before emission sampling begins:
    (1) For batch sampling, connect clean storage media, such as 
evacuated bags or tare-weighed PM sample media.
    (2) Operate the PEMS according to the instrument manufacturer's 
instructions and using good engineering judgment.
    (3) Operate PEMS heaters, dilution systems, sample pumps, cooling 
fans, and the data-collection system.
    (4) Pre-heat or pre-cool PEMS heat exchangers in the sampling system 
to within their tolerances for operating temperatures.
    (5) Allow all other PEMS components such as sample lines, filters, 
and pumps to stabilize at operating temperature.
    (6) Verify that no significant vacuum-side leak exists in the PEMS, 
as described in Sec.  1065.345.
    (7) Adjust PEMS flow rates to desired levels, using bypass flow if 
applicable.
    (8) Zero and span all PEMS gas analyzers using NIST-traceable gases 
that meet the specifications of Sec.  1065.750.
    (c) Start testing as follows:
    (1) Before the start of the first test interval, zero or re-zero any 
PEMS electronic integrating devices, as needed.
    (2) If the engine is already running and warmed up and starting is 
not part of field testing, start the field test by simultaneously 
starting to sample exhaust, record engine and ambient data, and 
integrate measured values using a PEMS.
    (3) If engine starting is part of field testing, start field testing 
by simultaneously starting to sample from the exhaust system, record 
engine and ambient data, and integrate measured values using a PEMS. 
Then start the engine.
    (d) Continue the test as follows:
    (1) Continue to sample exhaust, record data and integrate measured 
values throughout normal in-use operation of the engine.
    (2) Between each test interval, zero or re-zero any electronic 
integrating devices, and reset batch storage media, as needed.
    (3) The engine may be stopped and started, but continue to sample 
emissions throughout the entire field test.
    (4) Conduct periodic verifications such as zero and span 
verifications on PEMS gas analyzers and use these to correct for drift 
according to paragraph (g) of this section. Do not include data recorded 
during verifications in emission calculations. Conduct the verifications 
as follows:
    (i) For PEMS gas analyzers used to determine NTE emission values, 
perform verifications as recommended by the PEMS manufacturer or as 
indicated by good engineering judgment.
    (ii) For PEMS gas analyzers used to determine bin emission values, 
perform zero verifications at least hourly using purified air. Perform 
span verification at the end of the shift-day or more frequently as 
recommended by the PEMS manufacturer or as indicated by good engineering 
judgment.
    (5) You may periodically condition and analyze batch samples in-
situ, including PM samples; for example you may condition an inertial PM 
balance

[[Page 279]]

substrate if you use an inertial balance to measure PM.
    (6) You may have personnel monitoring and adjusting the PEMS during 
a test, or you may operate the PEMS unattended.
    (e) Stop testing as follows:
    (1) Continue sampling as needed to get an appropriate amount of 
emission measurement, according to the standard setting part. If the 
standard-setting part does not describe when to stop sampling, develop a 
written protocol before you start testing to establish how you will stop 
sampling. You may not determine when to stop testing based on emission 
results.
    (2) At the end of the field test, allow the sampling systems' 
response times to elapse and then stop sampling. Stop any integrators 
and indicate the end of the test cycle on the data-collection medium.
    (3) You may shut down the engine before or after you stop sampling.
    (f) For any proportional batch sample, such as a bag sample or PM 
sample, verify for each test interval whether or not proportional 
sampling was maintained according to Sec.  1065.545. Void the sample for 
any test interval that did not maintain proportional sampling according 
to Sec.  1065.545.
    (g) Take the following steps after emission sampling is complete:
    (1) As soon as practical after emission sampling, analyze any 
gaseous batch samples.
    (2) If you used dilution air, either analyze background samples or 
assume that background emissions were zero. Refer to Sec.  1065.140 for 
dilution-air specifications.
    (3) After quantifying all exhaust gases, record mean analyzer values 
after stabilizing a zero gas to each analyzer, then record mean analyzer 
values after stabilizing the span gas to the analyzer. Stabilization may 
include time to purge an analyzer of any sample gas and any additional 
time to account for analyzer response. Use these recorded values, 
including pre-test verifications and any zero verifications during 
testing, to correct for drift as described in Sec.  1065.550.
    (4) Verify PEMS gas analyzers used to determine NTE emission values 
as follows:
    (i) Invalidate any data that does not meet the range criteria in 
Sec.  1065.550. Note that it is acceptable that analyzers exceed 100% of 
their ranges when measuring emissions between test intervals, but not 
during test intervals. You do not have to retest an engine if the range 
criteria are not met.
    (ii) Invalidate any data that does not meet the drift criterion in 
Sec.  1065.550. For HC, invalidate any data if the difference between 
the uncorrected and the corrected brake-specific HC emission values are 
not within 10% of the uncorrected results or the 
applicable standard, whichever is greater. For data that does meet the 
drift criterion, correct those test intervals for drift according to 
Sec.  1065.672 and use the drift corrected results in emissions 
calculations.
    (5) Verify PEMS gas analyzers used to determine bin emission values 
as follows:
    (i) Invalidate data from a whole shift-day if more than 1% of 
recorded 1 Hz data exceeds 100% of the selected gas analyzer range. For 
analyzer outputs exceeding 100% of range, calculate emission results 
using the reported value. You must retest an engine if the range 
criteria are not met.
    (ii) Invalidate any data for periods in which the CO and 
CO2 gas analyzers do not meet the drift criterion in Sec.  
1065.550. For HC, invalidate data if the difference between the 
uncorrected and the corrected brake-specific HC emission values are not 
within 10% of the uncorrected results or the 
applicable standard, whichever is greater. For data that do meet the 
drift criterion, correct the data for drift according to Sec.  1065.672 
and use the drift-corrected results in emissions calculations.
    (iii) For PEMS NOX analyzers used to determine bin 
emission values, invalidate data for the engine over the entire shift-
day if any data do not meet the following drift limits instead of 
meeting the drift criteria specified in Sec.  1065.550:
    (A) The allowable analyzer zero-drift between successive zero 
verifications is 2.5 ppm. The analyzer zero-drift 
limit over the shift-day is 10 ppm.
    (B) The allowable analyzer span-drift limit is 4% of the measured span value between successive span 
verifications.

[[Page 280]]

    (6) Unless you weighed PM in-situ, such as by using an inertial PM 
balance, place any used PM samples into covered or sealed containers and 
return them to the PM-stabilization environment and weigh them as 
described in Sec.  1065.595.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37345, June 30, 2008; 
88 FR 4688, Jan. 24, 2023]



Sec.  1065.940  Emission calculations.

    (a) Perform emission calculations as described in Sec.  1065.650 to 
calculate brake-specific emissions for each test interval using any 
applicable information and instructions in the standard-setting part.
    (b) You may use a fixed molar mass for the diluted exhaust mixture 
for field testing. Determine this fixed value by engineering analysis.

[75 FR 68467, Nov. 8, 2010]



          Subpart K_Definitions and Other Reference Information



Sec.  1065.1001  Definitions.

    The definitions in this section apply to this part. The definitions 
apply to all subparts unless we note otherwise. All undefined terms have 
the meaning the Act gives them. The definitions follow:
    300 series stainless steel means any stainless steel alloy with a 
Unified Numbering System for Metals and Alloys number designated from 
S30100 to S39000. For all instances in this part where we specify 300 
series stainless steel, such parts must also have a smooth inner-wall 
construction. We recommend an average roughness, Ra, no 
greater than 4 [micro]m.
    Accuracy means the absolute difference between a reference quantity 
and the arithmetic mean of ten mean measurements of that quantity. 
Determine instrument accuracy, repeatability, and noise from the same 
data set. We specify a procedure for determining accuracy in Sec.  
1065.305.
    Act means the Clean Air Act, as amended, 42 U.S.C. 7401-7671q.
    Adjustable parameter means any device, system, or element of design 
that someone can adjust (including those which are difficult to access) 
and that, if adjusted, may affect emissions or engine performance during 
emission testing or normal in-use operation. This includes, but is not 
limited to, parameters related to injection timing and fueling rate. In 
some cases, this may exclude a parameter that is difficult to access if 
it cannot be adjusted to affect emissions without significantly 
degrading engine performance, or if it will not be adjusted in a way 
that affects emissions during in-use operation.
    Aerodynamic diameter means the diameter of a spherical water droplet 
that settles at the same constant velocity as the particle being 
sampled.
    Aftertreatment means relating to a catalytic converter, particulate 
filter, or any other system, component, or technology mounted downstream 
of the exhaust valve (or exhaust port) whose design function is to 
decrease emissions in the engine exhaust before it is exhausted to the 
environment. Exhaust-gas recirculation (EGR) and turbochargers are not 
aftertreatment.
    Allowed procedures means procedures that we either specify in this 
part 1065 or in the standard-setting part or approve under Sec.  
1065.10.
    Alternate procedures means procedures allowed under Sec.  
1065.10(c)(7).
    Applicable standard means an emission standard to which an engine is 
subject; or a family emission limit to which an engine is certified 
under an emission credit program in the standard-setting part.
    Aqueous condensation means the precipitation of water-containing 
constituents from a gas phase to a liquid phase. Aqueous condensation is 
a function of humidity, pressure, temperature, and concentrations of 
other constituents such as sulfuric acid. These parameters vary as a 
function of engine intake-air humidity, dilution-air humidity, engine 
air-to-fuel ratio, and fuel composition--including the amount of 
hydrogen and sulfur in the fuel.
    Atmospheric pressure means the wet, absolute, atmospheric static 
pressure. Note that if you measure atmospheric pressure in a duct, you 
must ensure that there are negligible pressure losses between the 
atmosphere and your measurement location, and you

[[Page 281]]

must account for changes in the duct's static pressure resulting from 
the flow.
    Auto-ranging means a gas analyzer function that automatically 
changes the analyzer digital resolution to a larger range of 
concentrations as the concentration approaches 100% of the analyzer's 
current range. Auto-ranging does not mean changing an analog amplifier 
gain within an analyzer.
    Auxiliary emission-control device means any element of design that 
senses temperature, motive speed, engine RPM, transmission gear, or any 
other parameter for the purpose of activating, modulating, delaying, or 
deactivating the operation of any part of the emission-control system.
    Average means the arithmetic mean of a sample.
    Brake power has the meaning given in the standard-setting part. If 
it is not defined in the standard-setting part, brake power means the 
usable power output of the engine, not including power required to fuel, 
lubricate, or heat the engine, circulate coolant to the engine, or to 
operate aftertreatment devices. If the engine does not power these 
accessories during a test, subtract the work required to perform these 
functions from the total work used in brake-specific emission 
calculations. Subtract engine fan work from total work only for air-
cooled engines.
    C1-equivalent means a convention of expressing HC concentrations 
based on the total number of carbon atoms present, such that the 
C1-equivalent of a molar HC concentration equals the molar 
concentration multiplied by the mean number of carbon atoms in each HC 
molecule. For example, the C1-equivalent of 10 [micro]mol/mol 
of propane (C3H8) is 30 [micro]mol/mol. 
C1-equivalent molar values may be denoted as ``ppmC'' in the 
standard-setting part. Molar mass may also be expressed on a 
C1 basis. Note that calculating HC masses from molar 
concentrations and molar masses is only valid where they are each 
expressed on the same carbon basis.
    Calibration means the process of setting a measurement system's 
response so that its output agrees with a range of reference signals. 
Contrast with ``verification''.
    Calibration gas means a purified gas mixture used to calibrate gas 
analyzers. Calibration gases must meet the specifications of Sec.  
1065.750. Note that calibration gases and span gases are qualitatively 
the same, but differ in terms of their primary function. Various 
performance verification checks for gas analyzers and sample handling 
components might refer to either calibration gases or span gases.
    Certification means relating to the process of obtaining a 
certificate of conformity for an engine family that complies with the 
emission standards and requirements in the standard-setting part.
    Compression-ignition means relating to a type of reciprocating, 
internal-combustion engine that is not a spark-ignition engine.
    Confidence interval means the range associated with a probability 
that a quantity will be considered statistically equivalent to a 
reference quantity.
    Constant-speed engine means an engine whose certification is limited 
to constant-speed operation. Engines whose constant-speed governor 
function is removed or disabled are no longer constant-speed engines.
    Constant-speed operation means engine operation with a governor that 
automatically controls the operator demand to maintain engine speed, 
even under changing load. Governors do not always maintain speed exactly 
constant. Typically speed can decrease (0.1 to 10) % below the speed at 
zero load, such that the minimum speed occurs near the engine's point of 
maximum power. (Note: An engine with an adjustable governor setting may 
be considered to operate at constant speed, subject to our approval. For 
such engines, the governor setting is considered an adjustable 
parameter.)
    Coriolis meter means a flow-measurement instrument that determines 
the mass flow of a fluid by sensing the vibration and twist of specially 
designed flow tubes as the flow passes through them. The twisting 
characteristic is called the Coriolis effect. According to Newton's 
Second Law of Motion, the amount of sensor tube twist is directly 
proportional to the mass flow rate of

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the fluid flowing through the tube. See Sec.  1065.220.
    Dewpoint means a measure of humidity stated as the equilibrium 
temperature at which water condenses under a given pressure from moist 
air with a given absolute humidity. Dewpoint is specified as a 
temperature in [deg]C or K, and is valid only for the pressure at which 
it is measured. See Sec.  1065.645 to determine water vapor mole 
fractions from dewpoints using the pressure at which the dewpoint is 
measured.
    Diesel exhaust fluid (DEF) means a liquid reducing agent (other than 
the engine fuel) used in conjunction with selective catalytic reduction 
to reduce NOX emissions. Diesel exhaust fluid is generally 
understood to be an aqueous solution of urea conforming to the 
specifications of ISO 18611 or ISO 22241.
    Dilution ratio (DR) means the amount of diluted exhaust per amount 
of undiluted exhaust.
    Discrete-mode means relating to a discrete-mode type of steady-state 
test, as described in the standard-setting part.
    Dispersion means either:
    (1) The broadening and lowering of a signal due to any fluid 
capacitance, fluid mixing, or electronic filtering in a sampling system. 
(Note: To adjust a signal so its dispersion matches that of another 
signal, you may adjust the system's fluid capacitance, fluid mixing, or 
electronic filtering.)
    (2) The mixing of a fluid, especially as a result of fluid 
mechanical forces or chemical diffusion.
    Drift means the difference between a zero or calibration signal and 
the respective value reported by a measurement instrument immediately 
after it was used in an emission test, as long as you zeroed and spanned 
the instrument just before the test.
    Dual-fuel has the meaning given in the standard-setting part.
    Duty cycle means one of the following:
    (1) A series of speed and torque values (or power values) that an 
engine must follow during a laboratory test. Duty cycles are specified 
in the standard-setting part. A single duty cycle may consist of one or 
more test intervals. A series of speed and torque values meeting the 
definition of this paragraph (1) may also be considered a test cycle. 
For example, a duty cycle may be a ramped-modal cycle, which has one 
test interval; a cold-start plus hot-start transient cycle, which has 
two test intervals; or a discrete-mode cycle, which has one test 
interval for each mode.
    (2) A set of weighting factors and the corresponding speed and 
torque values, where the weighting factors are used to combine the 
results of multiple test intervals into a composite result.
    Electric power generation application means an application whose 
purpose is to generate a precise frequency of electricity, which is 
characterized by an engine that controls engine speed very precisely. 
This would generally not apply to welders or portable home generators.
    Electronic control module means an engine's electronic device that 
uses data from engine sensors to control engine parameters.
    Emission-control system means any device, system, or element of 
design that controls or reduces the emissions of regulated pollutants 
from an engine.
    Emission-data engine means an engine that is tested for 
certification. This includes engines tested to establish deterioration 
factors.
    Emission-related maintenance means maintenance that substantially 
affects emissions or is likely to substantially affect emission 
deterioration.
    Engine family means a group of engines with similar emission 
characteristics throughout the useful life, as specified in the 
standard-setting part.
    Engine governed speed means the engine operating speed when it is 
controlled by the installed governor.
    Enhanced-idle means a mode of engine idle operation where idle speed 
is elevated above warm idle speed as determined by the electronic 
control module, for example during engine warm-up or to increase exhaust 
temperature.
    EPA Program Officer means the Director, Compliance Division, U.S. 
Environmental Protection Agency, 2000 Traverwood Dr., Ann Arbor, MI 
48105.
    Exhaust-gas recirculation means a technology that reduces emissions 
by routing exhaust gases that had been exhausted from the combustion 
chamber(s) back into the engine to be mixed

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with incoming air before or during combustion. The use of valve timing 
to increase the amount of residual exhaust gas in the combustion 
chamber(s) that is mixed with incoming air before or during combustion 
is not considered exhaust-gas recirculation for the purposes of this 
part.
    Fall time, t90-10, means the time interval of a 
measurement instrument's response after any step decrease to the input 
between the following points:
    (1) The point at which the response has fallen 10% of the total 
amount it will fall in response to the step change.
    (2) The point at which the response has fallen 90% of the total 
amount it will fall in response to the step change.
    Flexible-fuel has the meaning given in the standard-setting part.
    Flow-weighted mean means the mean of a quantity after it is weighted 
proportional to a corresponding flow rate. For example, if a gas 
concentration is measured continuously from the raw exhaust of an 
engine, its flow-weighted mean concentration is the sum of the products 
of each recorded concentration times its respective exhaust flow rate, 
divided by the sum of the recorded flow rates. As another example, the 
bag concentration from a CVS system is the same as the flow-weighted 
mean concentration, because the CVS system itself flow-weights the bag 
concentration.
    Fuel type means a general category of fuels such as gasoline or LPG. 
There can be multiple grades within a single type of fuel, such as all-
season and winter-grade gasoline.
    Good engineering judgment means judgments made consistent with 
generally accepted scientific and engineering principles and all 
available relevant information. See 40 CFR 1068.5 for the administrative 
process we use to evaluate good engineering judgment.
    HEPA filter means high-efficiency particulate air filters that are 
rated to achieve a minimum initial particle-removal efficiency of 99.97% 
using ASTM F1471 (incorporated by reference in Sec.  1065.1010).
    High-idle speed means the engine speed at which an engine governor 
function controls engine speed with operator demand at maximum and with 
zero load applied. ``Warm high-idle speed'' is the high-idle speed of a 
warmed-up engine.
    High-speed governor means any device, system, or element of design 
that modulates the engine output torque for the purpose of limiting the 
maximum engine speed.
    Hydraulic diameter means the diameter of a circle whose area is 
equal to the area of a noncircular cross section of tubing, including 
its wall thickness. The wall thickness is included only for the purpose 
of facilitating a simplified and nonintrusive measurement.
    Hydrocarbon (HC) means THC, THCE, NMHC, NMNEHC, NMOG, or NMHCE, as 
applicable. Hydrocarbon generally means the hydrocarbon group on which 
the emission standards are based for each type of fuel and engine.
    Identification number means a unique specification (for example, a 
model number/serial number combination) that allows someone to 
distinguish a particular engine from other similar engines.
    Idle speed means the engine speed at which an engine governor 
function controls engine speed with operator demand at minimum and with 
minimum load applied (greater than or equal to zero). For engines 
without a governor function that controls idle speed, idle speed means 
the manufacturer-declared value for lowest engine speed possible with 
minimum load. This definition does not apply for operation designated as 
``high-idle speed.'' ``Warm idle speed'' is the idle speed of a warmed-
up engine.
    Intermediate speed has the meaning given in Sec.  1065.610.
    Linearity means the degree to which measured values agree with 
respective reference values. Linearity is quantified using a linear 
regression of pairs of measured values and reference values over a range 
of values expected or observed during testing. Perfect linearity would 
result in an intercept, a0, equal to zero, a slope, 
a1, of one, a coefficient of determination, r\2\, of one, and 
a standard error of the estimate, SEE, of zero. The term ``linearity'' 
is not used in this part to refer to the shape of a measurement 
instrument's unprocessed response curve, such as a curve relating 
emission concentration to

[[Page 284]]

voltage output. A properly performing instrument with a nonlinear 
response curve will meet linearity specifications.
    Manufacturer has the meaning given in section 216(1) of the Act. In 
general, this term includes any person who manufactures an engine or 
vehicle for sale in the United States or otherwise introduces a new 
nonroad engine into commerce in the United States. This includes 
importers who import engines or vehicles for resale.
    Maximum test speed has the meaning given in Sec.  1065.610.
    Maximum test torque has the meaning given in Sec.  1065.610.
    Measurement allowance means a specified adjustment in the applicable 
emission standard or a measured emission value to reflect the relative 
quality of the measurement. See the standard-setting part to determine 
whether any measurement allowances apply for your testing. Measurement 
allowances generally apply only for field testing and are intended to 
account for reduced accuracy or precision that result from using field-
grade measurement systems.
    Mode means one of the following:
    (1) A distinct combination of engine speed and load for steady-state 
testing.
    (2) A continuous combination of speeds and loads specifying a 
transition during a ramped-modal test.
    (3) A distinct operator demand setting, such as would occur when 
testing locomotives or constant-speed engines.
    NIST-accepted means relating to a value that has been assigned or 
named by NIST.
    NIST-traceable means relating to a standard value that can be 
related to NIST-stated references through an unbroken chain of 
comparisons, all having stated uncertainties, as specified in NIST 
Technical Note 1297 (incorporated by reference in Sec.  1065.1010). 
Allowable uncertainty limits specified for NIST-traceability refer to 
the propagated uncertainty specified by NIST.
    Noise means the precision of 30 seconds of updated recorded values 
from a measurement instrument as it quantifies a zero or reference 
value. Determine instrument noise, repeatability, and accuracy from the 
same data set. We specify a procedure for determining noise in Sec.  
1065.305.
    No-load means a dynamometer setting of zero torque.
    Nonmethane hydrocarbon equivalent (NMHCE) means the sum of the 
carbon mass contributions of non-oxygenated nonmethane hydrocarbons, 
alcohols and aldehydes, or other organic compounds that are measured 
separately as contained in a gas sample, expressed as exhaust nonmethane 
hydrocarbon from petroleum-fueled engines. The hydrogen-to-carbon ratio 
of the equivalent hydrocarbon is 1.85:1.
    Nonmethane hydrocarbons (NMHC) means the sum of all hydrocarbon 
species except methane. Refer to Sec.  1065.660 for NMHC determination.
    Nonmethane nonethane hydrocarbon (NMNEHC) means the sum of all 
hydrocarbon species except methane and ethane. Refer to Sec.  1065.660 
for NMNEHC determination.
    Nonroad means relating to nonroad engines.
    Nonroad engine has the meaning we give in 40 CFR 1068.30. In general 
this means all internal-combustion engines except motor vehicle engines, 
stationary engines, engines used solely for competition, or engines used 
in aircraft.
    Open crankcase emissions means any flow from an engine's crankcase 
that is emitted directly into the environment. Crankcase emissions are 
not ``open crankcase emissions'' if the engine is designed to always 
route all crankcase emissions back into the engine (for example, through 
the intake system or an aftertreatment system) such that all the 
crankcase emissions, or their products, are emitted into the environment 
only through the engine exhaust system.
    Operator demand means an engine operator's input to control engine 
output. The ``operator'' may be a person (i.e., manual), or a governor 
(i.e., automatic) that mechanically or electronically signals an input 
that demands engine output. Input may be from an accelerator pedal or 
signal, a throttle-control lever or signal, a fuel lever or signal, a 
speed lever or signal, or a governor setpoint or signal. Output means 
engine power, P, which is the product

[[Page 285]]

of engine speed, fn, and engine torque, T.
    Oxides of nitrogen means NO and NO2 as measured by the 
procedures specified in Sec.  1065.270. Oxides of nitrogen are expressed 
quantitatively as if the NO is in the form of NO2, such that 
you use an effective molar mass for all oxides of nitrogen equivalent to 
that of NO2.
    Oxygenated fuels means fuels composed of at least 25% oxygen-
containing compounds, such as ethanol or methanol. Testing engines that 
use oxygenated fuels generally requires the use of the sampling methods 
in subpart I of this part. However, you should read the standard-setting 
part and subpart I of this part to determine appropriate sampling 
methods.
    Partial pressure means the pressure, p, attributable to a single gas 
in a gas mixture. For an ideal gas, the partial pressure divided by the 
total pressure is equal to the constituent's molar concentration, x.
    Percent (%) means a representation of exactly 0.01. Numbers 
expressed as percentages in this part (such as a tolerance of 2%) have infinite precision, so 2% and 2.000000000% have 
the same meaning. This means that where we specify some percentage of a 
total value, the calculated value has the same number of significant 
digits as the total value. For example, 2% of a span value where the 
span value is 101.3302 is 2.026604.
    Portable emission measurement system (PEMS) means a measurement 
system consisting of portable equipment that can be used to generate 
brake-specific emission measurements during field testing or laboratory 
testing.
    Precision means two times the standard deviation of a set of 
measured values of a single zero or reference quantity. See also the 
related definitions of noise and repeatability in this section.
    Procedures means all aspects of engine testing, including the 
equipment specifications, calibrations, calculations and other protocols 
and specifications needed to measure emissions, unless we specify 
otherwise.
    Proving ring is a device used to measure static force based on the 
linear relationship between stress and strain in an elastic material. It 
is typically a steel alloy ring, and you measure the deflection (strain) 
of its diameter when a static force (stress) is applied across its 
diameter.
    PTFE means polytetrafluoroethylene, commonly known as Teflon \TM\.
    Purified air means air meeting the specifications for purified air 
in Sec.  1065.750. Purified air may be produced by purifying ambient 
air. The purification may occur at the test site or at another location 
(such as at a gas supplier's facility). Alternatively, purified air may 
be synthetically generated, using good engineering judgment, from 
purified oxygen and nitrogen. The addition of other elements normally 
present in purified ambient air (such as Ar) is not required.
    Ramped-modal means relating to a ramped-modal type of steady-state 
test, as described in the standard-setting part.
    Recommend has the meaning given in Sec.  1065.201.
    Rechargeable Energy Storage System (RESS) means the components of a 
hybrid engine or vehicle that store recovered energy for later use, such 
as the battery system in a hybrid electric vehicle.
    Regression statistics means any of the regression statistics 
specified in Sec.  1065.602.
    Repeatability means the precision of ten mean measurements of a 
reference quantity. Determine instrument repeatability, accuracy, and 
noise from the same data set. We specify a procedure for determining 
repeatability in Sec.  1065.305.
    Revoke has the meaning given in 40 CFR 1068.30.
    Rise time, t10-90, means the time interval of a 
measurement instrument's response after any step increase to the input 
between the following points:
    (1) The point at which the response has risen 10% of the total 
amount it will rise in response to the step change.
    (2) The point at which the response has risen 90% of the total 
amount it will rise in response to the step change.
    Roughness (or average roughness, Ra) means the size of finely 
distributed vertical surface deviations from a smooth surface, as 
determined when traversing a surface. It is an integral of the absolute 
value of the roughness

[[Page 286]]

profile measured over an evaluation length.
    Round means to apply the rounding convention specified in Sec.  
1065.20(e), unless otherwise specified.
    Scheduled maintenance means adjusting, repairing, removing, 
disassembling, cleaning, or replacing components or systems periodically 
to keep a part or system from failing, malfunctioning, or wearing 
prematurely. It also may mean actions you expect are necessary to 
correct an overt indication of failure or malfunction for which periodic 
maintenance is not appropriate.
    Shared atmospheric pressure meter means an atmospheric pressure 
meter whose output is used as the atmospheric pressure for an entire 
test facility that has more than one dynamometer test cell.
    Shared humidity measurement means a humidity measurement that is 
used as the humidity for an entire test facility that has more than one 
dynamometer test cell.
    Span means to adjust an instrument so that it gives a proper 
response to a calibration standard that represents between 75% and 100% 
of the maximum value in the instrument range or expected range of use.
    Span gas means a purified gas mixture used to span gas analyzers. 
Span gases must meet the specifications of Sec.  1065.750. Note that 
calibration gases and span gases are qualitatively the same, but differ 
in terms of their primary function. Various performance verification 
checks for gas analyzers and sample handling components might refer to 
either calibration gases or span gases.
    Spark-ignition means relating to a gasoline-fueled engine or any 
other type of engine with a spark plug (or other sparking device) and 
with operating characteristics significantly similar to the theoretical 
Otto combustion cycle. Spark-ignition engines usually use a throttle to 
regulate intake air flow to control power during normal operation.
    Special procedures means procedures allowed under Sec.  
1065.10(c)(2).
    Specified procedures means procedures we specify in this part 1065 
or the standard-setting part. Other procedures allowed or required by 
Sec.  1065.10(c) are not specified procedures.
    Standard deviation has the meaning given in Sec.  1065.602. Note 
this is the standard deviation for a non-biased sample.
    Standard-setting part means the part in the Code of Federal 
Regulations that defines emission standards for a particular engine. See 
Sec.  1065.1(a).
    Steady-state means relating to emission tests in which engine speed 
and load are held at a finite set of nominally constant values. Steady-
state tests are generally either discrete-mode tests or ramped-modal 
tests.
    Stoichiometric means relating to the particular ratio of air and 
fuel such that if the fuel were fully oxidized, there would be no 
remaining fuel or oxygen. For example, stoichiometric combustion in a 
gasoline-fueled engine typically occurs at an air-to-fuel mass ratio of 
about 14.7:1.
    Storage medium means a particulate filter, sample bag, or any other 
storage device used for batch sampling.
    t0-50 means the time interval of a measurement system's 
response after any step increase to the input between the following 
points:
    (1) The point at which the step change is initiated at the sample 
probe.
    (2) The point at which the response has risen 50% of the total 
amount it will rise in response to the step change.
    t100-50 means the time interval of a measurement system's 
response after any step decrease to the input between the following 
points:
    (1) The point at which the step change is initiated at the sample 
probe.
    (2) The point at which the response has fallen 50% of the total 
amount it will fall in response to the step change.
    Test engine means an engine in a test sample.
    Test interval means a duration of time over which you determine mass 
of emissions. For example, the standard-setting part may specify a 
complete laboratory duty cycle as a cold-start test interval, plus a 
hot-start test interval. As another example, a standard-setting part may 
specify a field-test interval, such as a ``not-to-exceed'' (NTE) event, 
as a duration of time over which an engine operates within a certain 
range of speed and torque. In cases

[[Page 287]]

where multiple test intervals occur over a duty cycle, the standard-
setting part may specify additional calculations that weight and combine 
results to arrive at composite values for comparison against the 
applicable standards in this chapter.
    Test sample means the collection of engines selected from the 
population of an engine family for emission testing.
    Tolerance means the interval in which at least 95% of a set of 
recorded values of a certain quantity must lie. Use the specified 
recording frequencies and time intervals to determine if a quantity is 
within the applicable tolerance. The concept of tolerance is intended to 
address random variability. You may not take advantage of the tolerance 
specification to incorporate a bias into a measurement.
    Total hydrocarbon (THC) means the combined mass of organic compounds 
measured by the specified procedure for measuring total hydrocarbon, 
expressed as a hydrocarbon with a hydrogen-to-carbon mass ratio of 
1.85:1.
    Total hydrocarbon equivalent (THCE) means the sum of the carbon mass 
contributions of non-oxygenated hydrocarbons, alcohols and aldehydes, or 
other organic compounds that are measured separately as contained in a 
gas sample, expressed as exhaust hydrocarbon from petroleum-fueled 
engines. The hydrogen-to-carbon ratio of the equivalent hydrocarbon is 
1.85:1.
    Transformation time, t50, means the overall system 
response time to any step change in input, generally the average of the 
time to reach 50% response to a step increase, t0-50, or to a 
step decrease, t100-50.
    Uncertainty means uncertainty with respect to NIST-traceability. See 
the definition of NIST-traceable in this section.
    United States means the States, the District of Columbia, the 
Commonwealth of Puerto Rico, the Commonwealth of the Northern Mariana 
Islands, Guam, American Samoa, and the U.S. Virgin Islands.
    Useful life means the period during which a new engine is required 
to comply with all applicable emission standards. The standard-setting 
part defines the specific useful-life periods for individual engines.
    Variable-speed engine means an engine that is not a constant-speed 
engine.
    Vehicle means any vehicle, vessel, or type of equipment using 
engines to which this part applies. For purposes of this part, the term 
``vehicle'' may include nonmotive machines or equipment such as a pump 
or generator.
    Verification means to evaluate whether or not a measurement system's 
outputs agree with a range of applied reference signals to within one or 
more predetermined thresholds for acceptance. Contrast with 
``calibration''.
    We (us, our) means the Administrator of the Environmental Protection 
Agency and any authorized representatives.
    Work has the meaning given in Sec.  1065.110.
    Zero means to adjust an instrument so it gives a zero response to a 
zero calibration standard, such as purified nitrogen or purified air for 
measuring concentrations of emission constituents.
    Zero gas means a gas that yields a zero response in an analyzer. 
This may either be purified nitrogen, purified air, a combination of 
purified air and purified nitrogen. For field testing, zero gas may 
include ambient air.

[70 FR 40516, July 13, 2005, as amended at 73 FR 37346, June 30, 2008; 
73 FR 59342, Oct. 8, 2008; 74 FR 8428, Feb. 24, 2009; 74 FR 56518, Oct. 
30, 2009; 75 FR 23058, Apr. 30, 2010; 76 FR 57467, Sept. 15, 2011; 79 FR 
23814, Apr. 28, 2014; 81 FR 74191, Oct. 25, 2016; 86 FR 34575, June 29, 
2021; 88 FR 4689, Jan. 24, 2023]



Sec.  1065.1005  Symbols, abbreviations, acronyms, and units of measure.

    The procedures in this part generally follow the International 
System of Units (SI), as detailed in NIST Special Publication 811, which 
we incorporate by reference in Sec.  1065.1010. See Sec.  1065.20 for 
specific provisions related to these conventions. This section 
summarizes the way we use symbols, units of measure, and other 
abbreviations.
    (a) Symbols for quantities. This part uses the following symbols and 
units of measure for various quantities:

[[Page 288]]



                               Table 1 of Sec.   1065.1005--Symbols for Quantities
----------------------------------------------------------------------------------------------------------------
                                                                                           Units in terms of SI
         Symbol                 Quantity               Unit             Unit symbol             base units
----------------------------------------------------------------------------------------------------------------
[alpha].................  atomic hydrogen-to-  mole per mole......  mol/mol............  1.
                           carbon ratio.
A.......................  area...............  square meter.......  m2.................  m2.
a0......................  intercept of least
                           squares regression.
a1......................  slope of least
                           squares regression.
ag......................  acceleration of      meter per square     m/s2...............  m[middot] s-2.
                           Earth's gravity.     second.
[beta]..................  ratio of diameters.  meter per meter....  m/m................  1.
[beta]..................  atomic oxygen-to-    mole per mole......  mol/mol............  1.
                           carbon ratio.
C......................  number of carbon
                           atoms in a
                           molecule.
c.......................  power-specific       gram per kilowatt-   g/(kW[middot]hr)...  3.6-1 [middot] 10-9
                           carbon mass error    hour.                                     [middot] m-2 [middot]
                           coefficient.                                                   s2.
Cd......................  discharge
                           coefficient.
Cf......................  flow coefficient...
[delta].................  atomic nitrogen-to-  mole per mole......  mol/mol............  1.
                           carbon ratio.
d.......................  diameter...........  meter..............  m..................  m.
d.......................  power-specific       gram per kilowatt-   g/(kW[middot]hr)...  3.6-1 [middot] 10-9
                           carbon mass rate     hour.                                     [middot] m-2 [middot]
                           absolute error                                                 s2.
                           coefficent.
DR......................  dilution ratio.....  mole per mole......  mol/mol............  1.
[egr]...................  error between a
                           quantity and its
                           reference.
[isin]..................  difference or error
                           quantity.
e.......................  brake-specific       gram per kilowatt    g/(kW[middot]hr)...  3.6-1 [middot] 10-9
                           emission or fuel     hour.                                     [middot] m-2 [middot]
                           consumption.                                                   s2.
F.......................  F-test statistic...
[fnof]..................  frequency..........  hertz..............  Hz.................  s-1.
[fnof]n.................  angular speed        revolutions per      r/min..............  [pi] [middot] 30-1
                           (shaft).             minute.                                   [middot] s-1.
[gamma].................  ratio of specific    (joule per kilogram  (J/(kg[middot]K))/   1.
                           heats.               kelvin) per (joule   (J/(kg[middot]K)).
                                                per kilogram
                                                kelvin).
[gamma].................  atomic sulfur-to-    mole per mole......  mol/mol............  1.
                           carbon ratio.
[kappa].................  opacity
K.......................  correction factor..  ...................  ...................  1.
Kv......................  calibration          ...................  m4 [middot] s        m4 [middot] kg-1
                           coefficient.                              [middot] K0.5/kg.    [middot] s [middot]
                                                                                          K0.5.
l.......................  length.............  meter..............  m..................  m.
L.......................  limit..............
[micro].................  viscosity, dynamic.  pascal second......  Pa[middot]s........  m-1 [middot] kg
                                                                                          [middot] s-1.
M.......................  molar mass 1.......  gram per mole......  g/mol..............  10-3 [middot] kg
                                                                                          [middot] mol-1.
m.......................  mass...............  kilogram...........  kg.................  kg.
m.......................  mass rate..........  kilogram per second  kg/s...............  kg [middot] s-1.
v.......................  viscosity,           meter squared per    m2/s...............  m2 [middot] s-1.
                           kinematic.           second.
N.......................  total number in
                           series.
n.......................  amount of substance  mole...............  mol................  mol.
n.......................  amount of substance  mole per second....  mol/s..............  mol [middot] s-1.
                           rate.
P.......................  power..............  kilowatt...........  kW.................  103 [middot] m2
                                                                                          [middot] kg [middot] s-
                                                                                          3.
PF......................  penetration
                           fraction.
p.......................  pressure...........  pascal.............  Pa.................  m-1 [middot] kg
                                                                                          [middot] s-2.

[[Page 289]]

 
[rho]...................  mass density.......  kilogram per cubic   kg/m3..............  m-3 [middot] kg.
                                                meter.
[Delta]p................  differential static  pascal.............  Pa.................  m-1 [middot] kg
                           pressure.                                                      [middot] s-2.
r.......................  ratio of pressures.  pascal per pascal..  Pa/Pa..............  1.
r.......................  coefficient of
                           determination.
Ra......................  average surface      micrometer.........  [micro]m...........  10-6 [middot] m.
                           roughness.
Re.....................  Reynolds number....
RF......................  response factor....
RH......................  relative humidity..
[sigma].................  non-biased standard
                           deviation.
S.......................  Sutherland constant  kelvin.............  K..................  K.
SEE.....................  standard error of
                           the estimate.
T.......................  absolute             kelvin.............  K..................  K.
                           temperature.
T.......................  Celsius temperature  degree Celsius.....   [deg]C............  K-273.15.
T.......................  torque (moment of    newton meter.......  N[middot]m.........  m2 [middot] kg [middot]
                           force).                                                        s-2.
[theta].................  plane angle........  degrees............  [deg]..............  rad.
t.......................  time...............  second.............  s..................  s.
[Delta]t................  time interval,       second.............  s..................  s.
                           period, 1/
                           frequency.
V.......................  volume.............  cubic meter........  m3.................  m3.
V.......................  volume rate........  cubic meter per      m3/s...............  m3 [middot] s-1.
                                                second.
W.......................  work...............  kilowatt-hour......  kW[middot]hr.......  3.6 [middot] 106
                                                                                          [middot] m2 [middot]
                                                                                          kg [middot] s-2.
wC......................  carbon mass          gram per gram......  g/g................  1.
                           fraction.
x.......................  amount of substance  mole per mole......  mol/mol............  1.
                           mole fraction.2
X.......................  flow-weighted mean   mole per mole......  mol/mol............  1.
                           concentration.
y.......................  generic variable...
Z.......................  compressibility
                           factor.
----------------------------------------------------------------------------------------------------------------
1 See paragraph (f)(2) of this section for the values to use for molar masses. Note that in the cases of NOX and
  HC, the regulations specify effective molar masses based on assumed speciation rather than actual speciation.
2 Note that mole fractions for THC, THCE, NMHC, NMHCE, and NOTHC are expressed on a C1-equivalent basis.

    (b) Symbols for chemical species. This part uses the following 
symbols for chemical species and exhaust constituents:

  Table 2 of Sec.   1065.1005--Symbols for Chemical Species and Exhaust
                              Constituents
------------------------------------------------------------------------
                Symbol                              Species
------------------------------------------------------------------------
Ar...................................  argon.
C....................................  carbon.
CH2O.................................  formaldehyde.
CH2O2................................  formic acid.
CH3OH................................  methanol.
CH4..................................  methane.
C2H4O................................  acetaldehyde.
C2H5OH...............................  ethanol.
C2H6.................................  ethane.
C3H7OH...............................  propanol.
C3H8.................................  propane.
C4H10................................  butane.
C5H12................................  pentane.
CO...................................  carbon monoxide.
CO2..................................  carbon dioxide.
H....................................  atomic hydrogen.
H2...................................  molecular hydrogen.
H2O..................................  water.
H2SO4................................  sulfuric acid.
HC...................................  hydrocarbon.
He...................................  helium.
\85\Kr...............................  krypton 85.
N2...................................  molecular nitrogen.
NH3..................................  ammonia.
NMHC.................................  nonmethane hydrocarbon.
NMHCE................................  nonmethane hydrocarbon
                                        equivalent.
NMNEHC...............................  nonmethane-nonethane hydrocarbon.

[[Page 290]]

 
NO...................................  nitric oxide.
NO2..................................  nitrogen dioxide.
NOX..................................  oxides of nitrogen.
N2O..................................  nitrous oxide.
NMOG.................................  nonmethane organic gases.
NONMHC...............................  non-oxygenated nonmethane
                                        hydrocarbon.
NOTHC................................  non-oxygenated total hydrocarbon.
O2...................................  molecular oxygen.
OHC..................................  oxygenated hydrocarbon.
\210\Po..............................  polonium 210.
PM...................................  particulate matter.
S....................................  sulfur.
SVOC.................................  semi-volatile organic compound.
THC..................................  total hydrocarbon.
THCE.................................  total hydrocarbon equivalent.
ZrO2.................................  zirconium dioxide.
------------------------------------------------------------------------

    (c) Prefixes. This part uses the following prefixes for units and 
unit symbols:

                  Table 3 of Sec.   1065.1005--Prefixes
------------------------------------------------------------------------
              Symbol                     Prefix name          Factor
------------------------------------------------------------------------
[micro]...........................  micro...............            10-6
m.................................  milli...............            10-3
c.................................  centi...............            10-2
k.................................  kilo................             103
M.................................  mega................             106
------------------------------------------------------------------------

    (d) Superscripts. This part uses the following superscripts for 
modifying quantity symbols:

                Table 4 of Sec.   1065.1005--Superscripts
------------------------------------------------------------------------
                Superscript                            Meaning
------------------------------------------------------------------------
overbar (such as y).......................  arithmetic mean.
overdot (such as y).......................  quantity per unit time.
------------------------------------------------------------------------

    (e) Subscripts. This part uses the following subscripts for 
modifying quantity symbols:

                 Table 5 of Sec.   1065.1005--Subscripts
------------------------------------------------------------------------
                 Subscript                             Meaning
------------------------------------------------------------------------
a.........................................  absolute (e.g., absolute
                                             difference or error).
abs.......................................  absolute quantity.
act.......................................  actual condition.
air.......................................  air, dry.
amb.......................................  ambient.
atmos.....................................  atmospheric.
bkgnd.....................................  background.
C.........................................  carbon mass.
cal.......................................  calibration quantity.
CFV.......................................  critical flow venturi.
comb......................................  combined.
comp......................................  composite value.
cor.......................................  corrected quantity.
dil.......................................  dilution air.
dew.......................................  dewpoint.
dexh......................................  diluted exhaust.
dry.......................................  dry condition.
dutycycle.................................  duty cycle.
[isin]....................................  related to a difference or
                                             error quantity.
exh.......................................  raw exhaust.
exp.......................................  expected quantity.
fluid.....................................  fluid stream.
fn........................................  feedback speed.
frict.....................................  friction.
fuel......................................  fuel consumption.
hi,idle...................................  condition at high-idle.
i.........................................  an individual of a series.
idle......................................  condition at idle.
in........................................  quantity in.
init......................................  initial quantity, typically
                                             before an emission test.
int.......................................  intake air.
j.........................................  an individual of a series.
mapped....................................  conditions over which an
                                             engine can operate.
max.......................................  the maximum (i.e., peak)
                                             value expected at the
                                             standard over a test
                                             interval; not the maximum
                                             of an instrument range.
meas......................................  measured quantity.
media.....................................  PM sample media.
mix.......................................  mixture of diluted exhaust
                                             and air.
norm......................................  normalized.
out.......................................  quantity out.
P.........................................  power.
part......................................  partial quantity.
PDP.......................................  positive-displacement pump.
post......................................  after the test interval.
pre.......................................  before the test interval.
prod......................................  stoichiometric product.
r.........................................  relative (e.g., relative
                                             difference or error).
rate......................................  rate (divided by time).
record....................................  record rate.
ref.......................................  reference quantity.
rev.......................................  revolution.
sat.......................................  saturated condition.
s.........................................  slip.
span......................................  span quantity.
SSV.......................................  subsonic venturi.
std.......................................  standard condition.
stroke....................................  engine strokes per power
                                             stroke.
T.........................................  torque.
test......................................  test quantity.
test,alt..................................  alternate test quantity.
uncor.....................................  uncorrected quantity.
vac.......................................  vacuum side of the sampling
                                             system.
weight....................................  calibration weight.
zero......................................  zero quantity
------------------------------------------------------------------------

    (f) Constants.
    (1) This part uses the following constants for the composition of 
dry air:

[[Page 291]]



                 Table 6 of Sec.   1065.1005--Constants
------------------------------------------------------------------------
           Symbol                    Quantity               mol/mol
------------------------------------------------------------------------
[gamma]Arair...............  amount of argon in dry              0.00934
                              air.
[gamma]CO2air..............  amount of carbon                   0.000375
                              dioxide in dry air.
[gamma]N2air...............  amount of nitrogen in               0.78084
                              dry air.
[gamma]O2air...............  amount of oxygen in dry            0.209445
                              air.
------------------------------------------------------------------------

    (2) This part uses the following molar masses or effective molar 
masses of chemical species:

                Table 7 of Sec.   1065.1005--Molar Masses
------------------------------------------------------------------------
                                    g/mol (10-3[middot]kg[middot]mol-1)
    Symbol          Quantity
------------------------------------------------------------------------
Mair.........  molar mass of dry                      28.96559
                air 1.
MAr..........  molar mass of                            39.948
                argon.
MC...........  molar mass of                           12.0107
                carbon.
MCH3OH.......  molar mass of                          32.04186
                methanol.
MC2H5OH......  molar mass of                          46.06844
                ethanol.
MC2H4O.......  molar mass of                          44.05256
                acetaldehyde.
MCH4N2O......  molar mass of urea                     60.05526
MC2H6........  molar mass of                          30.06904
                ethane.
MC3H8........  molar mass of                          44.09562
                propane.
MC3H7OH......  molar mass of                          60.09502
                propanol.
MCO..........  molar mass of                           28.0101
                carbon monoxide.
MCH4.........  molar mass of                           16.0425
                methane.
MCO2.........  molar mass of                           44.0095
                carbon dioxide.
MH...........  molar mass of                           1.00794
                atomic hydrogen.
MH2..........  molar mass of                           2.01588
                molecular
                hydrogen.
MH2O.........  molar mass of                          18.01528
                water.
MCH2O........  molar mass of                          30.02598
                formaldehyde.
MHe..........  molar mass of                          4.002602
                helium.
MN...........  molar mass of                           14.0067
                atomic nitrogen.
MN2..........  molar mass of                           28.0134
                molecular
                nitrogen.
MNH3.........  molar mass of                          17.03052
                ammonia.
MNMHC........  effective C1 molar                    13.875389
                mass of
                nonmethane
                hydrocarbon 2.
MNMHCE.......  effective C1 molar                    13.875389
                mass of
                nonmethane
                hydrocarbon
                equivalent 2.
MNMNEHC......  effective C1 molar                    13.875389
                mass of
                nonmethane-
                nonethane
                hydrocarbon 2.
MNOx.........  effective molar                         46.0055
                mass of oxides of
                nitrogen 3.
MN2O.........  molar mass of                           44.0128
                nitrous oxide.
MO...........  molar mass of                           15.9994
                atomic oxygen.
MO2..........  molar mass of                           31.9988
                molecular oxygen.
MS...........  molar mass of                            32.065
                sulfur.
MTHC.........  effective C1 molar                    13.875389
                mass of total
                hydrocarbon 2.
MTHCE........  effective C1 molar                    13.875389
                mass of total
                hydrocarbon
                equivalent 2.
------------------------------------------------------------------------
1 See paragraph (f)(1) of this section for the composition of dry air.
2 The effective molar masses of THC, THCE, NMHC, NMHCE, and NMNEHC are
  defined on a C1 basis and are based on an atomic hydrogen-to-carbon
  ratio, [alpha], of 1.85 (with [beta], [gamma], and [delta] equal to
  zero).
3 The effective molar mass of NOX is defined by the molar mass of
  nitrogen dioxide, NO2.

    (3) This part uses the following molar gas constant for ideal gases:

     Table 8 of Sec.   1065.1005--Molar Gas Constant for Ideal Gases
------------------------------------------------------------------------
                                                    J/(mol[middot]K)
                                               (m\2\[middot]kg[middot]s-
         Symbol                Quantity             \2\[middot]mol-
                                                   \1\[middot]K-\1\)
------------------------------------------------------------------------
R......................  molar gas constant..                8.314472
------------------------------------------------------------------------

    (4) This part uses the following ratios of specific heats for 
dilution air and diluted exhaust:

 Table 9 of Sec.   1065.1005--Ratios of Specific Heats for Dilution Air
                           and Diluted Exhaust
------------------------------------------------------------------------
                                                      [J/(kg[middot]K)]/
           Symbol                    Quantity          [J/(kg[middot]K)]
------------------------------------------------------------------------
[gamma]air.................  ratio of specific heats               1.399
                              for intake air or
                              dilution air.
[gamma]dil.................  ratio of specific heats               1.399
                              for diluted exhaust.
[gamma]exh.................  ratio of specific heats               1.385
                              for raw exhaust.
------------------------------------------------------------------------

    (g) Other acronyms and abbreviations. This part uses the following 
additional abbreviations and acronyms:

[[Page 292]]



     Table 10 of Sec.   1065.1005--Other Acronyms and Abbreviations
------------------------------------------------------------------------
                Acronym                              Meaning
------------------------------------------------------------------------
ABS....................................  acrylonitrile-butadiene-
                                          styrene.
ASTM...................................  ASTM International.
BMD....................................  bag mini-diluter.
BSFC...................................  brake-specific fuel
                                          consumption.
CARB...................................  California Air Resources Board.
CFR....................................  Code of Federal Regulations.
CFV....................................  critical-flow venturi.
CI.....................................  compression-ignition.
CITT...................................  Curb Idle Transmission Torque.
CLD....................................  chemiluminescent detector.
CVS....................................  constant-volume sampler.
DEF....................................  diesel exhaust fluid.
DF.....................................  deterioration factor.
ECM....................................  electronic control module.
EFC....................................  electronic flow control.
e.g....................................  exempli gratia, for example.
EGR....................................  exhaust gas recirculation.
EPA....................................  Environmental Protection
                                          Agency.
FEL....................................  Family Emission Limit.
FID....................................  flame-ionization detector.
FTIR...................................  Fourier transform infrared.
GC.....................................  gas chromatograph.
GC-ECD.................................  gas chromatograph with an
                                          electron-capture detector.
GC-FID.................................  gas chromatograph with a flame
                                          ionization detector.
HEPA...................................  high-efficiency particulate
                                          air.
IBP....................................  initial boiling point.
IBR....................................  incorporated by reference.
i.e....................................  id est, in other words.
ISO....................................  International Organization for
                                          Standardization.
LPG....................................  liquefied petroleum gas.
MPD....................................  magnetopneumatic detection.
NDIR...................................  nondispersive infrared.
NDUV...................................  nondispersive ultraviolet.
NIST...................................  National Institute for
                                          Standards and Technology.
NMC....................................  nonmethane cutter.
PDP....................................  positive-displacement pump.
PEMS...................................  portable emission measurement
                                          system.
PFD....................................  partial-flow dilution.
PLOT...................................  porous layer open tubular.
PMD....................................  paramagnetic detection.
PMP....................................  Polymethylpentene.
pt.....................................  a single point at the mean
                                          value expected at the
                                          standard.
psi....................................  pounds per square inch.
PTFE...................................  polytetrafluoroethylene
                                          (commonly known as TeflonTM).
RE.....................................  rounding error.
RESS...................................  rechargeable energy storage
                                          system.
RFPF...................................  response factor penetration
                                          fraction.
RMC....................................  ramped-modal cycle.
rms....................................  root-mean square.
RTD....................................  resistive temperature detector.
SAW....................................  surface acoustic wave.
SEE....................................  standard error of the estimate.
SSV....................................  subsonic venturi.
SI.....................................  spark-ignition.
THC-FID................................  total hydrocarbon flame
                                          ionization detector.
TINV...................................  inverse student t-test function
                                          in Microsoft Excel.
UCL....................................  upper confidence limit.
UFM....................................  ultrasonic flow meter.
U.S.C..................................  United States Code
------------------------------------------------------------------------


[79 FR 23815, Apr. 28, 2014, as amended at 81 FR 74191, Oct. 25, 2016; 
86 FR 34575, June 29, 2021; 87 FR 64866, Oct. 26, 2022; 88 FR 4689, Jan. 
24, 2023]



Sec.  1065.1010  Incorporation by reference.

    Certain material is incorporated by reference into this part with 
the approval of the Director of the Federal Register under 5 U.S.C. 
552(a) and 1 CFR part 51. To enforce any edition other than that 
specified in this section, EPA must publish a document in the Federal 
Register and the material must be available to the public. All approved 
incorporation by reference (IBR) material is available for inspection at 
EPA and at the National Archives and Records Administration (NARA). 
Contact EPA at: U.S. EPA, Air and Radiation Docket Center, WJC West 
Building, Room 3334, 1301 Constitution Ave. NW, Washington, DC 20004; 
www.epa.gov/dockets; (202) 202-1744. For information on inspecting this 
material at NARA, visit www.archives.gov/federal-register /cfr/ibr-
locations.html or email [email protected]. The material may be 
obtained from the following sources:
    (a) ASTM material. The following standards are available from ASTM 
International, 100 Barr Harbor Dr., P.O. Box C700, West Conshohocken, PA 
19428-2959, (877) 909-ASTM, or http://www.astm.org:
    (1) ASTM D86-12, Standard Test Method for Distillation of Petroleum 
Products at Atmospheric Pressure, approved December 1, 2012 (``ASTM 
D86''), IBR approved for Sec. Sec.  1065.703(b) and 1065.710(b) and (c).
    (2) ASTM D93-13, Standard Test Methods for Flash Point by Pensky-
Martens Closed Cup Tester, approved July 15, 2013 (``ASTM D93''), IBR 
approved for Sec.  1065.703(b).
    (3) ASTM D130-12, Standard Test Method for Corrosiveness to Copper 
from Petroleum Products by Copper

[[Page 293]]

Strip Test, approved November 1, 2012 (``ASTM D130''), IBR approved for 
Sec.  1065.710(b).
    (4) ASTM D381-12, Standard Test Method for Gum Content in Fuels by 
Jet Evaporation, approved April 15, 2012 (``ASTM D381''), IBR approved 
for Sec.  1065.710(b).
    (5) ASTM D445-12, Standard Test Method for Kinematic Viscosity of 
Transparent and Opaque Liquids (and Calculation of Dynamic Viscosity), 
approved April 15, 2012 (``ASTM D445''), IBR approved for Sec.  
1065.703(b).
    (6) ASTM D525-12a, Standard Test Method for Oxidation Stability of 
Gasoline (Induction Period Method), approved September 1, 2012 (``ASTM 
D525''), IBR approved for Sec.  1065.710(b).
    (7) ASTM D613-13, Standard Test Method for Cetane Number of Diesel 
Fuel Oil, approved December 1, 2013 (``ASTM D613''), IBR approved for 
Sec.  1065.703(b).
    (8) ASTM D910-13a, Standard Specification for Aviation Gasolines, 
approved December 1, 2013 (``ASTM D910''), IBR approved for Sec.  
1065.701(f).
    (9) ASTM D975-13a, Standard Specification for Diesel Fuel Oils, 
approved December 1, 2013 (``ASTM D975''), IBR approved for Sec.  
1065.701(f).
    (10) ASTM D1267-12, Standard Test Method for Gage Vapor Pressure of 
Liquefied Petroleum (LP) Gases (LP-Gas Method), approved November 1, 
2012 (``ASTM D1267''), IBR approved for Sec.  1065.720(a).
    (11) ASTM D1319-13, Standard Test Method for Hydrocarbon Types in 
Liquid Petroleum Products by Fluorescent Indicator Adsorption, approved 
May 1, 2013 (``ASTM D1319''), IBR approved for Sec.  1065.710(c).
    (12) ASTM D1655-13a, Standard Specification for Aviation Turbine 
Fuels, approved December 1, 2013 (``ASTM D1655''), IBR approved for 
Sec.  1065.701(f).
    (13) ASTM D1837-11, Standard Test Method for Volatility of Liquefied 
Petroleum (LP) Gases, approved October 1, 2011 (``ASTM D1837''), IBR 
approved for Sec.  1065.720(a).
    (14) ASTM D1838-12a, Standard Test Method for Copper Strip Corrosion 
by Liquefied Petroleum (LP) Gases, approved December 1, 2012 (``ASTM 
D1838''), IBR approved for Sec.  1065.720(a).
    (15) ASTM D1945-03 (Reapproved 2010), Standard Test Method for 
Analysis of Natural Gas by Gas Chromatography, approved January 1, 2010 
(``ASTM D1945''), IBR approved for Sec.  1065.715(a).
    (16) ASTM D2158-11, Standard Test Method for Residues in Liquefied 
Petroleum (LP) Gases, approved January 1, 2011 (``ASTM D2158''), IBR 
approved for Sec.  1065.720(a).
    (17) ASTM D2163-07, Standard Test Method for Determination of 
Hydrocarbons in Liquefied Petroleum (LP) Gases and Propane/Propene 
Mixtures by Gas Chromatography, approved December 1, 2007 (``ASTM 
D2163''), IBR approved for Sec.  1065.720(a).
    (18) ASTM D2598-12, Standard Practice for Calculation of Certain 
Physical Properties of Liquefied Petroleum (LP) Gases from Compositional 
Analysis, approved November 1, 2012 (``ASTM D2598''), IBR approved for 
Sec.  1065.720(a).
    (19) ASTM D2622-16, Standard Test Method for Sulfur in Petroleum 
Products by Wavelength Dispersive X-ray Fluorescence Spectrometry, 
approved January 1, 2016 (``ASTM D2622''), IBR approved for Sec. Sec.  
1065.703(b) and 1065.710(b) and (c).
    (20) ASTM D2699-13b, Standard Test Method for Research Octane Number 
of Spark-Ignition Engine Fuel, approved October 1, 2013 (``ASTM 
D2699''), IBR approved for Sec.  1065.710(b).
    (21) ASTM D2700-13b, Standard Test Method for Motor Octane Number of 
Spark-Ignition Engine Fuel, approved October 1, 2013 (``ASTM D2700''), 
IBR approved for Sec.  1065.710(b).
    (22) ASTM D2713-13, Standard Test Method for Dryness of Propane 
(Valve Freeze Method), approved October 1, 2013 (``ASTM D2713''), IBR 
approved for Sec.  1065.720(a).
    (23) ASTM D2880-13b, Standard Specification for Gas Turbine Fuel 
Oils, approved November 15, 2013 (``ASTM D2880''), IBR approved for 
Sec.  1065.701(f).
    (24) ASTM D2986-95a, Standard Practice for Evaluation of Air Assay 
Media by the Monodisperse DOP (Dioctyl Phthalate) Smoke Test, approved 
September 10, 1995 (``ASTM D2986''), IBR approved for Sec.  1065.170(c). 
(Note: This standard was withdrawn by ASTM.)

[[Page 294]]

    (25) ASTM D3231-13, Standard Test Method for Phosphorus in Gasoline, 
approved June 15, 2013 (``ASTM D3231''), IBR approved for Sec.  
1065.710(b) and (c).
    (26) ASTM D3237-12, Standard Test Method for Lead in Gasoline By 
Atomic Absorption Spectroscopy, approved June 1, 2012 (``ASTM D3237''), 
IBR approved for Sec.  1065.710(b) and (c).
    (27) ASTM D4052-11, Standard Test Method for Density, Relative 
Density, and API Gravity of Liquids by Digital Density Meter, approved 
October 15, 2011 (``ASTM D4052''), IBR approved for Sec.  1065.703(b).
    (28) ASTM D4629-12, Standard Test Method for Trace Nitrogen in 
Liquid Petroleum Hydrocarbons by Syringe/Inlet Oxidative Combustion and 
Chemiluminescence Detection, approved April 15, 2012 (``ASTM D4629''), 
IBR approved for Sec.  1065.655(e).
    (29) ASTM D4814-13b, Standard Specification for Automotive Spark-
Ignition Engine Fuel, approved December 1, 2013 (``ASTM D4814''), IBR 
approved for Sec.  1065.701(f).
    (30) ASTM D4815-13, Standard Test Method for Determination of MTBE, 
ETBE, TAME, DIPE, tertiary-Amyl Alcohol and C1 to C4 Alcohols in 
Gasoline by Gas Chromatography, approved October 1, 2013 (``ASTM 
D4815''), IBR approved for Sec.  1065.710(b).
    (31) ASTM D5186-03 (Reapproved 2009), Standard Test Method for 
Determination of the Aromatic Content and Polynuclear Aromatic Content 
of Diesel Fuels and Aviation Turbine Fuels By Supercritical Fluid 
Chromatography, approved April 15, 2009 (``ASTM D5186''), IBR approved 
for Sec.  1065.703(b).
    (32) ASTM D5191-13, Standard Test Method for Vapor Pressure of 
Petroleum Products (Mini Method), approved December 1, 2013 (``ASTM 
D5191''), IBR approved for Sec.  1065.710(b) and (c).
    (33) ASTM D5291-10, Standard Test Methods for Instrumental 
Determination of Carbon, Hydrogen, and Nitrogen in Petroleum Products 
and Lubricants, approved May 1, 2010 (``ASTM D5291''), IBR approved for 
Sec.  1065.655(e).
    (34) ASTM D5453-19a, Standard Test Method for Determination of Total 
Sulfur in Light Hydrocarbons, Spark Ignition Engine Fuel, Diesel Engine 
Fuel, and Engine Oil by Ultraviolet Fluorescence, approved July 1, 2019 
(``ASTM D5453''), IBR approved for Sec. Sec.  1065.703(b) and 
1065.710(b).
    (35) ASTM D5599-00 (Reapproved 2010), Standard Test Method for 
Determination of Oxygenates in Gasoline by Gas Chromatography and Oxygen 
Selective Flame Ionization Detection, approved October 1, 2010 (``ASTM 
D5599''), IBR approved for Sec. Sec.  1065.655(e) and 1065.710(b).
    (36) ASTM D5762-12 Standard Test Method for Nitrogen in Petroleum 
and Petroleum Products by Boat-Inlet Chemiluminescence, approved April 
15, 2012 (``ASTM D5762''), IBR approved for Sec.  1065.655(e).
    (37) ASTM D5769-10, Standard Test Method for Determination of 
Benzene, Toluene, and Total Aromatics in Finished Gasolines by Gas 
Chromatography/Mass Spectrometry, approved May 1, 2010 (``ASTM D5769''), 
IBR approved for Sec.  1065.710(b).
    (38) ASTM D5797-13, Standard Specification for Fuel Methanol (M70- 
M85) for Automotive Spark-Ignition Engines, approved June 15, 2013 
(``ASTM D5797''), IBR approved for Sec.  1065.701(f).
    (39) ASTM D5798-13a, Standard Specification for Ethanol Fuel Blends 
for Flexible Fuel Automotive Spark-Ignition Engines, approved June 15, 
2013 (``ASTM D5798''), IBR approved for Sec.  1065.701(f).
    (40) ASTM D6348-12e1, Standard Test Method for Determination of 
Gaseous Compounds by Extractive Direct Interface Fourier Transform 
Infrared (FTIR) Spectroscopy, approved February 1, 2012 (``ASTM 
D6348''), IBR approved for Sec. Sec.  1065.266(b) and 1065.275(b).
    (41) ASTM D6550-10, Standard Test Method for Determination of Olefin 
Content of Gasolines by Supercritical-Fluid Chromatography, approved 
October 1, 2010 (``ASTM D6550''), IBR approved for Sec.  1065.710(b).
    (42) ASTM D6615-11a, Standard Specification for Jet B Wide-Cut 
Aviation Turbine Fuel, approved October 1, 2011 (``ASTM D6615''), IBR 
approved for Sec.  1065.701(f).
    (43) ASTM D6667-14 (Reapproved 2019), Standard Test Method for 
Determination of Total Volatile Sulfur in Gaseous Hydrocarbons and 
Liquefied

[[Page 295]]

Petroleum Gases by Ultraviolet Fluorescence, approved May 1, 2019 
(``ASTM D6667''), IBR approved for Sec.  1065.720(a).
    (44) ASTM D6751-12, Standard Specification for Biodiesel Fuel Blend 
Stock (B100) for Middle Distillate Fuels, approved August 1, 2012 
(``ASTM D6751''), IBR approved for Sec.  1065.701(f).
    (45) ASTM D6985-04a, Standard Specification for Middle Distillate 
Fuel Oil--Military Marine Applications, approved November 1, 2004 
(``ASTM D6985''), IBR approved for Sec.  1065.701(f). (Note: This 
standard was withdrawn by ASTM.)
    (46) ASTM D7039-15a (Reapproved 2020), Standard Test Method for 
Sulfur in Gasoline, Diesel Fuel, Jet Fuel, Kerosine, Biodiesel, 
Biodiesel Blends, and Gasoline-Ethanol Blends by Monochromatic 
Wavelength Dispersive X-ray Fluorescence Spectrometry, approved May 1, 
2020 (``ASTM D7039''), IBR approved for Sec. Sec.  1065.703(b) and 
1065.710(b).
    (47) ASTM F1471-09, Standard Test Method for Air Cleaning 
Performance of a High- Efficiency Particulate Air Filter System, 
approved March 1, 2009 (``ASTM F1471''), IBR approved for Sec.  
1065.1001.
    (b) California Air Resources Board material. The following documents 
are available from the California Air Resources Board, Haagen-Smit 
Laboratory, 9528 Telstar Ave., El Monte, CA 91731-2908, (800) 242-4450, 
or http://www.arb.ca.gov:
    (1) California Non-Methane Organic Gas Test Procedures, Amended July 
30, 2002, Mobile Source Division, California Air Resources Board, IBR 
approved for Sec.  1065.805(f).
    (2) [Reserved]
    (c) Institute of Petroleum material. The following documents are 
available from the Energy Institute, 61 New Cavendish St., London, W1G 
7AR, UK, or by calling + 44-(0)20-7467-7100, or at http://
www.energyinst.org:
    (1) IP-470, 2005, Determination of aluminum, silicon, vanadium, 
nickel, iron, calcium, zinc, and sodium in residual fuels by atomic 
absorption spectrometry, IBR approved for Sec.  1065.705(b).
    (2) IP-500, 2003, Determination of the phosphorus content of 
residual fuels by ultra-violet spectrometry, IBR approved for Sec.  
1065.705(b).
    (3) IP-501, 2005, Determination of aluminum, silicon, vanadium, 
nickel, iron, sodium, calcium, zinc and phosphorus in residual fuel oil 
by ashing, fusion and inductively coupled plasma emission spectrometry, 
IBR approved for Sec.  1065.705(b).
    (d) ISO material. The following standards are available from the 
International Organization for Standardization, 1, ch. de la Voie-
Creuse, CP 56, CH-1211 Geneva 20, Switzerland, 41-22-749-01-11, or 
http://www.iso.org:

    (1) ISO 2719:2002, Determination of flash point--Pensky-Martens 
closed cup method (``ISO 2719''), IBR approved for Sec.  1065.705(c).
    (2) ISO 3016:1994, Petroleum products--Determination of pour point 
(``ISO 3016''), IBR approved for Sec.  1065.705(c).
    (3) ISO 3104:1994/Cor 1:1997, Petroleum products--Transparent and 
opaque liquids--Determination of kinematic viscosity and calculation of 
dynamic viscosity (``ISO 3104''), IBR approved for Sec.  1065.705(c).
    (4) ISO 3675:1998, Crude petroleum and liquid petroleum products--
Laboratory determination of density--Hydrometer method (``ISO 3675''), 
IBR approved for Sec.  1065.705(c).
    (5) ISO 3733:1999, Petroleum products and bituminous materials--
Determination of water--Distillation method (``ISO 3733''), IBR approved 
for Sec.  1065.705(c).
    (6) ISO 6245:2001, Petroleum products--Determination of ash (``ISO 
6245''), IBR approved for Sec.  1065.705(c).
    (7) ISO 8217:2012(E), Petroleum products--Fuels (class F)--
Specifications of marine fuels, Fifth edition, August 15, 2012 (``ISO 
8217''), IBR approved for Sec.  1065.705(b) and (c).
    (8) ISO 8754:2003, Petroleum products--Determination of sulfur 
content--Energy-dispersive X-ray Fluorescence spectrometry (``ISO 
8754''), IBR approved for Sec.  1065.705(c).
    (9) ISO 10307-2(E):2009, Petroleum products--Total sediment in 
residual fuel oils--Part 2: Determination using standard procedures for 
ageing, Second Ed., February 1, 2009 (``ISO 10307''), as modified by ISO 
10307-2:2009/Cor.1:2010(E), Technical Corrigendum 1, published May 15, 
2010, IBR approved for Sec.  1065.705(c).
    (10) ISO 10370:1993/Cor 1:1996, Petroleum products--Determination of 
carbon residue--Micro method (``ISO 10370''), IBR approved for Sec.  
1065.705(c).
    (11) ISO 10478:1994, Petroleum products--Determination of aluminium 
and silicon in fuel oils--Inductively coupled plasma emission and atomic 
absorption spectroscopy methods (``ISO 10478''), IBR approved for Sec.  
1065.705(c).
    (12) ISO 12185:1996/Cor 1:2001, Crude petroleum and petroleum 
products--Determination of density--Oscillating U-tube method (``ISO 
12185''), IBR approved for Sec.  1065.705(c).

[[Page 296]]

    (13) ISO 14596:2007, Petroleum products--Determination of sulfur 
content--Wavelength-dispersive X-ray fluorescence spectrometry (``ISO 
14596''), IBR approved for Sec.  1065.705(c).
    (14) ISO 14597:1997, Petroleum products--Determination of vanadium 
and nickel content--Wavelength dispersive X-ray fluorescence 
spectrometry (``ISO 14597''), IBR approved for Sec.  1065.705(c).
    (15) ISO 14644-1:1999, Cleanrooms and associated controlled 
environments (``ISO 14644''), IBR approved for Sec.  1065.190(b).
    (e) NIST material. The following documents are available from 
National Institute of Standards and Technology, 100 Bureau Drive, Stop 
1070, Gaithersburg, MD 20899-1070, (301) 975-6478, or www.nist.gov:
    (1) NIST Special Publication 811, 2008 Edition, Guide for the Use of 
the International System of Units (SI), March 2008, IBR approved for 
Sec. Sec.  1065.20(a) and 1065.1005.
    (2) NIST Technical Note 1297, 1994 Edition, Guidelines for 
Evaluating and Expressing the Uncertainty of NIST Measurement Results, 
IBR approved for Sec.  1065.1001.
    (f) SAE International material. The following standards are 
available from SAE International, 400 Commonwealth Dr., Warrendale, PA 
15096-0001, (724) 776-4841, or http://www.sae.org:
    (1) SAE 770141, 1977, Optimization of Flame Ionization Detector for 
Determination of Hydrocarbon in Diluted Automotive Exhausts, Glenn D. 
Reschke, IBR approved for Sec.  1065.360(c).
    (2) SAE J1151, Methane Measurement Using Gas Chromatography, 
stabilized September 2011, IBR approved for Sec. Sec.  1065.267(b) and 
1065.750(a).

[79 FR 23818, Apr. 28, 2014, as amended at 81 FR 74193, Oct. 25, 2016; 
85 FR 78468, Dec. 4, 2020; 86 FR 34579, June 29, 2021; 88 FR 4690, Jan. 
24, 2023]



Subpart L_Methods for Unregulated and Special Pollutants and Additional 
                               Procedures

    Source: 79 FR 23820, Apr. 28, 2014, unless otherwise noted.



Sec.  1065.1101  Applicability.

    This subpart specifies procedures that may be used to measure 
emission constituents that are not measured (or not separately measured) 
by the test procedures in the other subparts of this part. These 
procedures are included to facilitate consistent measurement of 
unregulated pollutants for purposes other than compliance with emission 
standards. Unless otherwise specified in the standard-setting part, use 
of these procedures is optional and does not replace any requirements in 
the rest of this part.

                     Semi-Volatile Organic Compounds



Sec.  1065.1103  General provisions for SVOC measurement.

    The provisions of Sec. Sec.  1065.1103 through 1065.1111 specify 
procedures for measuring semi-volatile organic compounds (SVOC) along 
with PM. These sections specify how to collect a sample of the SVOCs 
during exhaust emission testing, as well as how to use wet chemistry 
techniques to extract SVOCs from the sample media for analysis. Note 
that the precise method you use will depend on the category of SVOCs 
being measured. For example, the method used to measure polynuclear 
aromatic hydrocarbons (PAHs) will differ slightly from the method used 
to measure dioxins. Follow standard analytic chemistry methods for any 
aspects of the analysis that are not specified.
    (a) Laboratory cleanliness is especially important throughout SVOC 
testing. Thoroughly clean all sampling system components and glassware 
before testing to avoid sample contamination. For the purposes of this 
subpart, the sampling system is defined as sample pathway from the 
sample probe inlet to the downstream most point where the sample is 
captured (in this case the condensate trap).
    (b) We recommend that media blanks be analyzed for each batch of 
sample media (sorbent, filters, etc.) prepared for testing. Blank 
sorbent modules (i.e., field blanks) should be stored in a sealed 
environment and should periodically accompany the test sampling system 
throughout the course of a test, including sampling system and sorbent 
module disassembly, sample packaging, and storage. Use good engineering 
judgment to determine the frequency with which you should generate field 
blanks. The field blank sample

[[Page 297]]

should be close to the sampler during testing.
    (c) We recommend the use of isotope dilution techniques, including 
the use of isotopically labeled surrogate, internal, alternate, and 
injection standards.
    (d) If your target analytes degrade when exposed to ultraviolet 
radiation, such as nitropolynuclear aromatic hydrocarbons (nPAHs), 
perform these procedures in the dark or with ultraviolet filters 
installed over the lights.
    (e) The following definitions and abbreviations apply for SVOC 
measurements:
    (1) Soxhlet extraction means the extraction method invented by Franz 
von Soxhlet, in which the sample is placed in a thimble and rinsed 
repeatedly with a recycle of the extraction solvent.
    (2) XAD-2 means a hydrophobic crosslinked polystyrene copolymer 
resin adsorbent known commercially as Amberlite[supreg] XAD[supreg]-2, 
or an equivalent adsorbent like XAD-4.
    (3) Semi-volatile organic compound (SVOC) means an organic compound 
that is sufficiently volatile to exist in vapor form in engine exhaust, 
but that readily condenses to liquid or solid form under atmospheric 
conditions. Most SVOCs have at least 14 carbon atoms per molecule or 
they have a boiling point between (240 and 400) [deg]C. SVOCs include 
dioxin, quinone, and nitro-PAH compounds. They may be a natural 
byproduct of combustion or they may be created post-combustion. Note 
that SVOCs may be included in measured values of hydrocarbons and/or PM 
using the procedures specified in this part.
    (4) Kuderna-Danish concentrator means laboratory glassware known by 
this name that consists of an air-cooled condenser on top of an 
extraction bulb.
    (5) Dean-Stark trap means laboratory glassware known by this name 
that uses a reflux condenser to collect water from samples extracted 
under reflux.
    (6) PUF means polyurethane foam.
    (7) Isotopically labeled means relating to a compound in which 
either all the hydrogen atoms are replaced with the atomic isotope 
hydrogen-2 (deuterium) or one of the carbon atoms at a defined position 
in the molecule is replaced with the atomic isotope carbon-13.



Sec.  1065.1105  Sampling system design.

    (a) General. We recommend that you design your SVOC batch sampler to 
extract sample from undiluted emissions to maximize the sampled SVOC 
quantity. If you dilute your sample, we recommend using annular 
dilution. If you dilute your sample, but do not use annular dilution, 
you must precondition your sampling system to reach equilibrium with 
respect to loss and re-entrainment of SVOCs to the walls of the sampling 
system. To the extent practical, adjust sampling times based on the 
emission rate of target analytes from the engine to obtain analyte 
concentrations above the detection limit. In some instances you may need 
to run repeat test cycles without replacing the sample media or 
disassembling the batch sampler.
    (b) Sample probe, transfer lines, and sample media holder design and 
construction. The sampling system should consist of a sample probe, 
transfer line, PM filter holder, cooling coil, sorbent module, and 
condensate trap. Construct sample probes, transfer lines, and sample 
media holders that have inside surfaces of nickel, titanium or another 
nonreactive material capable of withstanding raw exhaust gas 
temperatures. Seal all joints in the hot zone of the system with gaskets 
made of nonreactive material similar to that of the sampling system 
components. You may use teflon gaskets in the cold zone. We recommend 
locating all components as close to probes as practical to shorten 
sampling system length and minimize the surface exposed to engine 
exhaust.
    (c) Sample system configuration. This paragraph (c) specifies the 
components necessary to collect SVOC samples, along with our recommended 
design parameters. Where you do not follow our recommendations, use good 
engineering judgment to design your sampling system so it does not 
result in loss of SVOC during sampling. The sampling system should 
contain the following components in series in the order listed:
    (1) Use a sample probe similar to the PM sample probe specified in 
subpart B of this part.
    (2) Use a PM filter holder similar to the holder specified in 
subpart B of this part, although you will likely need to

[[Page 298]]

use a larger size to accommodate the high sample flow rates. We 
recommend using a 110 mm filter for testing spark ignition engines or 
engines that utilize exhaust aftertreatment for PM removal and a 293 mm 
filter for other engines. If you are not analyzing separately for SVOCs 
in gas and particle phases, you do not have to control the temperature 
of the filter holder. Note that this differs from normal PM sampling 
procedures, which maintain the filter at a much lower temperature to 
capture a significant fraction of exhaust SVOC on the filter. In this 
method, SVOCs that pass through the filter will be collected on the 
downstream sorbent module. If you are collecting SVOCs in gas and 
particle phases, control your filter face temperature according to Sec.  
1065.140(e)(4).
    (3) Use good engineering judgment to design a cooling coil that will 
drop the sample temperature to approximately 5 [deg]C. Note that 
downstream of the cooling coil, the sample will be a mixture of vapor 
phase hydrocarbons in CO2, air, and a primarily aqueous 
liquid phase.
    (4) Use a hydrophobic sorbent in a sealed sorbent module. Note that 
this sorbent module is intended to be the final stage for collecting the 
SVOC sample and should be sized accordingly. We recommend sizing the 
module to hold 40 g of XAD-2 along with PUF plugs at either end of the 
module, noting that you may vary the mass of XAD used for testing based 
on the anticipated SVOC emission concentration and sample flow rate.
    (5) Include a condensate trap to separate the aqueous liquid phase 
from the gas stream. We recommend using a peristaltic pump to remove 
water from the condensate trap over the course of the test to prevent 
build-up of the condensate. Note that for some tests it may be 
appropriate to collect this water for analysis.
    (d) Sampler flow control. For testing using the recommended filter 
and sorbent module sizes, we recommend targeting an average sample flow 
rate of 70 liters per minute to maximize SVOC collection. The sampler 
must be designed to maintain proportional sampling throughout the test. 
Verify proportional sampling after an emission test as described in 
Sec.  1065.545.
    (e) Water bath. Design the sample system with a water bath in which 
the cooling coil, sorbent module, and condensate trap will be submerged. 
Use a heat exchanger or ice to maintain the bath temperature at (3 to 7) 
[deg]C.

[79 FR 23820, Apr. 28, 2014, as amended at 81 FR 74195, Oct. 25, 2016]



Sec.  1065.1107  Sample media and sample system preparation;
sample system assembly.

    This section describes the appropriate types of sample media and the 
cleaning procedure required to prepare the media and wetted sample 
surfaces for sampling.
    (a) Sample media. The sampling system uses two types of sample media 
in series: The first to simultaneously capture the PM and associated 
particle phase SVOCs, and a second to capture SVOCs that remain in the 
gas phase, as follows:
    (1) For capturing PM, we recommend using pure quartz filters with no 
binder if you are not analyzing separately for SVOCs in gas and particle 
phases. If you are analyzing separately, you must use 
polytetrafluoroethylene (PTFE) filters with PTFE support. Select the 
filter diameter to minimize filter change intervals, accounting for the 
expected PM emission rate, sample flow rate. Note that when repeating 
test cycles to increase sample mass, you may replace the filter without 
replacing the sorbent or otherwise disassembling the batch sampler. In 
those cases, include all filters in the extraction.
    (2) For capturing gaseous SVOCs, utilize XAD-2 resin with or without 
PUF plugs. Note that two PUF plugs are typically used to contain the 
XAD-2 resin in the sorbent module.
    (b) Sample media and sampler preparation. Prepare pre-cleaned PM 
filters and pre-cleaned PUF plugs/XAD-2 as needed. Store sample media in 
containers protected from light and ambient air if you do not use them 
immediately after cleaning. Use the following preparation procedure, or 
an analogous procedure with different solvents and extraction times:
    (1) Pre-clean the filters via Soxhlet extraction with methylene 
chloride for

[[Page 299]]

24 hours and dry over dry nitrogen in a low-temperature vacuum oven.
    (2) Pre-clean PUF and XAD-2 with a series of Soxhlet extractions: 8 
hours with water, 22 hours with methanol, 22 hours with methylene 
chloride, and 22 hours with toluene, followed by drying with nitrogen.
    (3) Clean sampler components, including the probe, filter holder, 
condenser, sorbent module, and condensate collection vessel by rinsing 
three times with methylene chloride and then three times with toluene. 
Prepare pre-cleaned aluminum foil for capping the probe inlet of the 
sampler after the sampling system has been assembled.
    (c) Sorbent spiking. Use good engineering judgment to verify the 
extent to which your extraction methods recover SVOCs absorbed on the 
sample media. We recommend spiking the XAD-2 resin with a surrogate 
standard before testing with a carbon-13 or hydrogen-2 isotopically 
labeled standard for each of the class of analytes targeted for 
analysis. Perform this spiking as follows:
    (1) Insert the lower PUF plug into the bottom of the sorbent module.
    (2) Add half of one portion of XAD-2 resin to the module and spike 
the XAD-2 in the module with the standard.
    (3) Wait 1 hour for the solvent from the standard(s) to evaporate, 
add the remaining 20 g of the XAD-2 resin to the module, and then insert 
a PUF plug in the top of the sorbent module.
    (4) Cover the inlet and outlet of the sorbent module with pre-
cleaned aluminum foil.
    (d) Sampling system assembly. After preparing the sample media and 
the sampler, assemble the condensate trap, cooling coil, filter holder 
with filter, sample probe, and sorbent module, then lower the assembly 
into the reservoir. Cover the probe inlet with pre-cleaned aluminum 
foil.

[79 FR 23820, Apr. 28, 2014, as amended at 81 FR 74195, Oct. 25, 2016]



Sec.  1065.1109  Post-test sampler disassembly and sample extraction.

    This section describes the process for disassembling and rinsing the 
sampling system and extracting and cleaning up the sample.
    (a) Sampling system disassembly. Disassemble the sampling system in 
a clean environment as follows after the test:
    (1) Remove the PM filter, PUF plugs, and all the XAD-2 from the 
sampling system and store them at or below 5 [deg]C until analysis.
    (2) Rinse sampling system wetted surfaces upstream of the condensate 
trap with acetone followed by toluene (or a comparable solvent system), 
ensuring that all the solvent remaining in liquid phase is collected 
(note that a fraction of the acetone and toluene will likely be lost to 
evaporation during mixing). Rinse with solvent volumes that are 
sufficient to cover all the surfaces exposed to the sample during 
testing. We recommend three fresh solvent rinses with acetone and two 
with toluene. We recommend rinse volumes of 60 ml per rinse for all 
sampling system components except the condenser coil, of which you 
should use 200 ml per rinse. Keep the acetone rinsate separate from the 
toluene rinsate to the extent practicable. Rinsate fractions should be 
stored separately in glass bottles that have been pre-rinsed with 
acetone, hexane, and toluene (or purchase pre-cleaned bottles).
    (3) Use good engineering judgment to determine if you should analyze 
the aqueous condensate phase for SVOCs. If you determine that analysis 
is necessary, use toluene to perform a liquid-liquid extraction of the 
SVOCs from the collected aqueous condensate using a separatory funnel or 
an equivalent method. Add the toluene from this aqueous extraction to 
the toluene rinsate fraction described in paragraph (a)(2) of this 
section.
    (4) Reduce rinsate solvent volumes as needed using a Kuderna-Danish 
concentrator or rotary evaporator and retain these rinse solvents for 
reuse during sample media extraction for the same test. Be careful to 
avoid loss of low molecular weight analytes when concentrating with 
rotary evaporation.
    (b) Sample extraction. Extract the SVOCs from the sorbent using 
Soxhlet extraction as described in this paragraph (b). Two 16 hour 
extractions are necessary to accommodate the Soxhlet extractions of all 
SVOCs from a single sample. This reduces the possibility of

[[Page 300]]

losing low molecular weight SVOCs and promotes water removal. We 
recommend performing the first extraction with acetone/hexane and the 
second using toluene (or an equivalent solvent system). You may 
alternatively use an equivalent method such as an automated solvent 
extractor.
    (1) We recommend equipping the Soxhlet extractor with a Dean-Stark 
trap to facilitate removal of residual water from the sampling system 
rinse. The Soxhlet apparatus must be large enough to allow extraction of 
the PUF, XAD-2, and filter in a single batch. Include in the extractor 
setup a glass thimble with a coarse or extra coarse sintered glass 
bottom. Pre-clean the extractor using proper glass-cleaning procedures. 
We recommend that the Soxhlet apparatus be cleaned with a (4 to 8) hour 
Soxhlet extraction with methylene chloride at a cycling rate of three 
cycles per hour. Discard the solvent used for pre-cleaning (no analysis 
is necessary).
    (2) Load the extractor thimble before placing it in the extractor by 
first rolling the PM filter around the inner circumference of the 
thimble, with the sampled side facing in. Push one PUF plug down into 
the bottom of the thimble, add approximately half of the XAD-2, and then 
spike the XAD-2 in the thimble with the isotopically labeled extraction 
standards of known mass. Target the center of the XAD-2 bed for 
delivering the extraction standard. We recommend using multiple 
isotopically labeled extraction standards that cover the range of target 
analytes. This generally means that you should use isotopically labeled 
standards at least for the lowest and highest molecular weight analytes 
for each category of compounds (such as PAHs and dioxins). These 
extraction standards monitor the efficiency of the extraction and are 
also used to determine analyte concentrations after analysis. Upon 
completion of spiking, add the remaining XAD-2 to the thimble, insert 
the remaining PUF plug, and place the thimble into the extractor. Note 
that if you are collecting and analyzing for SVOCs in gas and particle 
phases, perform separate extractions for the filter and XAD-2.
    (3) For the initial extraction, combine the concentrated acetone 
rinses (from the sampling system in paragraph (a) of this section) with 
enough hexane to bring the solvent volume up to the target level of 700 
ml. Assemble the extractor and turn on the heating controls and cooling 
water. Allow the sample to reflux for 16 hours with the rheostat 
adjusted to cycle the extraction at a rate of (3.0 0.5) cycles per hour. Drain the water from the Dean-
Stark trap as it accumulates by opening the stopcock on the trap. Set 
aside the water for analysis or discard it. In most cases, any water 
present will be removed within approximately 2 hours after starting the 
extraction.
    (4) After completing the initial extraction, remove the solvent and 
concentrate it to (4.0 0.5) ml using a Kuderna-
Danish concentrator that includes a condenser such as a three-ball 
Snyder column with venting dimples and a graduated collection tube. Hold 
the water bath temperature at (75 to 80) [deg]C. Using this concentrator 
will minimize evaporative loss of analytes with lower molecular weight.
    (i) Rinse the round bottom flask of the extractor with (60 to 100) 
ml of hexane and add the rinsate to this concentrated extract.
    (ii) Concentrate the mixture to (4 0.5) ml 
using a Kuderna-Danish concentrator or similar apparatus.
    (iii) Repeat the steps in paragraphs (b)(4)(i) and (ii) of this 
section three times, or as necessary to remove all the residual solvent 
from the round bottom flask of the extractor, concentrating the final 
rinsate to (4 0.5) ml.
    (5) For the second extraction, combine the toluene rinses (from the 
sampling system in paragraph (a) of this section) with any additional 
toluene needed to bring the solvent volume up to the target level of 700 
ml. As noted in paragraph (a) of this section, you may need to 
concentrate the rinsate before adding it to the extraction apparatus if 
the rinsate solvent volume is too large. Allow the sample to reflux for 
16 hours with the rheostat adjusted to cycle the extraction at a rate of 
(3.0 0.5) cycles per hour. Check the Dean-Stark 
trap for water during the first 2 hours of the extraction (though little

[[Page 301]]

or no water should be present during this stage).
    (6) Upon completion of the second extraction, remove the solvent and 
concentrate it to (4 0.5) ml as described in 
paragraph (b)(4) of this section. Using hexane from paragraph (b)(4) of 
this section as the rinse solvent effectively performs a solvent 
exchange of toluene with hexane.
    (7) Combine the concentrated extract from paragraph (b)(4) of this 
section with the concentrated extract from paragraph (b)(6) of this 
section. Divide the extract into a number of fractions based on the 
number of analyses you need to perform. Perform the separate sample 
clean-up described in paragraph (c) of this section as needed for each 
fraction.
    (c) Sample clean-up. This paragraph (c) describes how to perform 
sample cleaning to remove from the sample extract any solids and any 
SVOCs that will not be analyzed. This process, known as ``sample clean-
up'', reduces the potential for interference or co-elution of peaks 
during analytical analysis. Before performing the sample clean-up, spike 
the extract with an alternate standard that contains a known mass of 
isotopically labeled compounds that are identical to the target analytes 
(except for the labeling). The category of the target analyte compounds 
(such as PAHs or dioxin) will determine the number of compounds that 
make up the standard. For example, PAHs require the use of four 
compounds in the alternate standard to cover the four basic ring 
structures of PAHs (2-ring, 3-ring, 4-ring, and 5-ring structures). 
These alternate standards are used to monitor the efficiency of the 
clean-up procedure. Before sample clean-up, concentrate the fractionated 
sample to about 2 ml with a Kuderna-Danish concentrator or rotary 
evaporator, and then transfer the extract to an 8 ml test tube with 
hexane rinse. Concentrate it to a volume of about 1 ml using a Kuderna-
Danish concentrator. Use good engineering judgment to select an 
appropriate column chromatographic clean-up option for your target 
analytes. Note that these clean-up techniques generally remove compounds 
based on their polarity. The following procedures are examples of clean-
up techniques for PAHs and nPAHs.
    (1) PAH clean-up. The following method is appropriate for clean-up 
of extracts intended for analysis of PAHs:
    (i) Pack a glass gravity column (250 mm x 10 mm recommended) by 
inserting a clean glass wool plug into the bottom of the column and add 
10 g of activated silica gel in methylene chloride. Tap the column to 
settle the silica gel and then add a 1 cm layer of anhydrous sodium 
sulfate. Verify the volume of solvent required to completely elute all 
the PAHs and adjust the weight of the silica gel accordingly to account 
for variations among batches of silica gel that may affect the elution 
volume of the various PAHs.
    (ii) Elute the column with 40 ml of hexane. The rate for all 
elutions should be about 2 ml/min. You may increase the elution rate by 
using dry air or nitrogen to maintain the headspace slightly above 
atmospheric pressure. Discard the eluate just before exposing the sodium 
sulfate layer to the air or nitrogen and transfer the 1 ml sample 
extract onto the column using two additional 2 ml rinses of hexane. Just 
before exposing the sodium sulfate layer to the air or nitrogen, begin 
elution of the column with 25 ml of hexane followed by 25 ml of 40 
volume % methylene chloride in hexane. Collect the entire eluate and 
concentrate it to about 5 ml using the Kuderna-Danish concentrator or a 
rotary evaporator. Make sure not to evaporate all the solvent from the 
extract during the concentration process. Transfer the eluate to a small 
sample vial using a hexane rinse and concentrate it to 100 [micro]l 
using a stream of nitrogen without violently disturbing the solvent. 
Store the extracts in a refrigerator at or below 4 [deg]C, and away from 
light.
    (2) nPAH clean up. The following procedure, adapted from 
``Determination and Comparison of Nitrated-Polycyclic Aromatic 
Hydrocarbons Measured in Air and Diesel Particulate Reference 
Materials'' (Bamford, H.A., et al, Chemosphere, Vol. 50, Issue 5, pages 
575-587), is an appropriate method to clean up extracts intended for 
analysis of nPAHs:
    (i) Condition an aminopropyl solid phase extraction (SPE) cartridge 
by

[[Page 302]]

eluting it with 20 ml of 20 volume % methylene chloride in hexane. 
Transfer the extract quantitatively to the SPE cartridge with at least 
two methylene chloride rinses. Elute the extract through the SPE 
cartridge by using 40 ml of 20 volume % methylene chloride in hexane to 
minimize potential interference of polar constituents, and then reduce 
the extract to 0.5 ml in hexane and subject it to normal-phase liquid 
chromatography using a pre-prepared 9.6 mm x 25 cm semi-preparative 
Chromegabond[supreg] amino/cyano column (5 [micro]m particle size) to 
isolate the nPAH fraction. The mobile phase is 20 volume % methylene 
chloride in hexane at a constant flow rate of 5 ml per minute. Back-
flash the column with 60 ml of methylene chloride and then condition it 
with 200 ml of 20 volume % methylene chloride in hexane before each 
injection. Collect the effluent and concentrate it to about 2 ml using 
the Kuderna-Danish concentrator or a rotary evaporator. Transfer it to a 
minivial using a hexane rinse and concentrate it to 100 [micro]l using a 
gentle stream of nitrogen. Store the extracts at or below 4 [deg]C, and 
away from light.
    (ii) [Reserved]

[79 FR 23820, Apr. 28, 2014, as amended at 81 FR 74195, Oct. 25, 2016]



Sec.  1065.1111  Sample analysis.

    This subpart does not specify chromatographic or analytical methods 
to analyze extracts, because the appropriateness of such methods is 
highly dependent on the nature of the target analytes. However, we 
recommend that you spike the extract with an injection standard that 
contains a known mass of an isotopically labeled compound that is 
identical to one of the target analytes (except for labeling). This 
injection standard allows you to monitor the efficiency of the 
analytical process by verifying the volume of sample injected for 
analysis.

                  Vanadium Sublimation In SCR Catalysts

    Source: Sections 1065.1113 through 1065.1119 appear at 88 FR 4691, 
Jan. 24, 2023, unless otherwise noted.



Sec.  1065.1113  General provisions related to vanadium sublimation 
temperatures in SCR catalysts.

    Sections 1065.1113 through 1065.1121 specify procedures for 
determining vanadium emissions from a catalyst based on catalyst 
temperature. Vanadium can be emitted from the surface of SCR catalysts 
at temperatures above 550 [deg]C, dependent on the catalyst formulation. 
These procedures are appropriate for measuring the vanadium sublimation 
product from a reactor by sampling onto an equivalent mass of alumina 
and performing analysis by Inductively Coupled Plasma--Optical Emission 
Spectroscopy (ICP-OES). Follow standard analytic chemistry methods for 
any aspects of the analysis that are not specified.
    (a) The procedure is adapted from ``Behavior of Titania-supported 
Vanadia and Tungsta SCR Catalysts at High Temperatures in Reactant 
Streams: Tungsten and Vanadium Oxide and Hydroxide Vapor Pressure 
Reduction by Surficial Stabilization'' (Chapman, D.M., Applied Catalysis 
A: General, 2011, 392, 143-150) with modifications to the acid digestion 
method from ``Measuring the trace elemental composition of size-resolved 
airborne particles'' (Herner, J.D. et al, Environmental Science and 
Technology, 2006, 40, 1925-1933).
    (b) Laboratory cleanliness is especially important throughout 
vanadium testing. Thoroughly clean all sampling system components and 
glassware before testing to avoid sample contamination.



Sec.  1065.1115  Reactor design and setup.

    Vanadium measurements rely on a reactor that adsorbs sublimation 
vapors of vanadium onto an alumina capture bed with high surface area.
    (a) Configure the reactor with the alumina capture bed downstream of 
the catalyst in the reactor's hot zone to adsorb vanadium vapors at high 
temperature. You may use quartz beads upstream of the catalyst to help 
stabilize reactor gas temperatures. Select an alumina material and 
design the reactor to minimize sintering of the alumina. For a 1-inch 
diameter reactor, use 4 to 5 g of \1/8\ inch extrudates or -14/+24 mesh 
(approximately 0.7 to 1.4 mm)

[[Page 303]]

gamma alumina (such as Alfa Aesar, aluminum oxide, gamma, catalyst 
support, high surface area, bimodal). Position the alumina downstream 
from either an equivalent amount of -14/+24 mesh catalyst sample or an 
approximately 1-inch diameter by 1 to 3-inch long catalyst-coated 
monolith sample cored from the production-intent vanadium catalyst 
substrate. Separate the alumina from the catalyst with a 0.2 to 0.4 g 
plug of quartz wool. Place a short 4 g plug of quartz wool downstream of 
the alumina to maintain the position of that bed. Use good engineering 
judgment to adjust as appropriate for reactors of different sizes.
    (b) Include the quartz wool with the capture bed to measure vanadium 
content. We recommend analyzing the downstream quartz wool separately 
from the alumina to see if the alumina fails to capture some residual 
vanadium.
    (c) Configure the reactor such that both the sample and capture beds 
are in the reactor's hot zone. Design the reactor to maintain similar 
temperatures in the capture bed and catalyst. Monitor the catalyst and 
alumina temperatures with Type K thermocouples inserted into a 
thermocouple well that is in contact with the catalyst sample bed.
    (d) If there is a risk that the quartz wool and capture bed are not 
able to collect all the vanadium, configure the reactor with an 
additional capture bed and quartz wool plug just outside the hot zone 
and analyze the additional capture bed and quartz wool separately.
    (e) An example of a catalyst-coated monolith and capture bed 
arrangement in the reactor tube are shown in the following figure:

 Figure 1 to paragraph (e) of Sec.  1065.1115-- Example of Reactor Setup


    [GRAPHIC] [TIFF OMITTED] TR24JA23.141
    
    (f) You may need to account for vanadium-loaded particles 
contaminating catalyst-coated monoliths as a result of physical 
abrasion. To do this, determine how much titanium is in the capture bed 
and compare to an alumina blank. Using these values and available 
information about the ratio of vanadium to titanium in the catalyst, 
subtract the mass of vanadium catalyst material associated with the 
catalyst particles from the total measured vanadium on the capture bed 
to determine the vanadium recovered due to sublimation.

[[Page 304]]



Sec.  1065.1117  Reactor aging cycle for determination of vanadium
sublimation temperature.

    This section describes the conditions and process required to 
operate the reactor described in Sec.  1065.1115 for collection of the 
vanadium sublimation samples for determination of vanadium sublimation 
temperature. The reactor aging cycle constitutes the process of testing 
the catalyst sample over all the test conditions described in paragraph 
(b) of this section.
    (a) Set up the reactor to flow gases with a space velocity of at 
least 35,000/hr with a pressure drop across the catalyst and capture 
beds less than 35 kPa. Use test gases meeting the following 
specifications, noting that not all gases will be used at the same time:
    (1) 5 vol% O2, balance N2.
    (2) NO, balance N2. Use an NO concentration of (200 to 
500) ppm.
    (3) NH3, balance N2. Use an NH3 
concentration of (200 to 500) ppm.
    (b) Perform testing as follows:
    (1) Add a new catalyst sample and capture bed into the reactor as 
described in Sec.  1065.1113. Heat the reactor to 550 [deg]C while 
flowing the oxygen blend specified in paragraph (a)(1) of this section 
as a pretest gas mixture. Ensure that no H2O is added to the 
pretest gas mixture to reduce the risk of sintering and vanadium 
sublimation.
    (2) Start testing at a temperature that is lower than the point at 
which vanadium starts to sublime. Start testing when the reactor reaches 
550 [deg]C unless testing supports a lower starting temperature. Once 
the reactor reaches the starting temperature and the catalyst has been 
equilibrated to the reactor temperature, flow NO and NH3 test 
gases for 18 hours with a nominal H2O content of 5 volume 
percent. If an initial starting temperature of 550 [deg]C results in 
vanadium sublimation, you may retest using a new catalyst sample and a 
lower initial starting temperature.
    (3) After 18 hours of exposure, flow the pretest oxygen blend as 
specified in paragraph (b)(1) of this section and allow the reactor to 
cool down to room temperature.
    (4) Analyze the sample as described in Sec.  1065.1121.
    (5) Repeat the testing in paragraphs (b)(1) through (4) of this 
section by raising the reactor temperature in increments of 50 [deg]C up 
to the temperature at which vanadium sublimation begins.
    (6) Once sublimation has been detected, repeat the testing in 
paragraphs (b)(1) through (4) of this section by decreasing the reactor 
temperature in increments of 25 [deg]C until the vanadium concentration 
falls below the sublimation threshold.
    (7) Repeat the testing in paragraphs (b)(1) through (6) of this 
section with a nominal H2O concentration of 10 volume percent 
or the maximum water concentration expected at the standard.
    (8) You may optionally test in a manner other than testing a single 
catalyst formulation in series across all test temperatures. For 
example, you may test additional samples at the same reactor temperature 
before moving on to the next temperature.
    (c) The effective sublimation temperature for the tested catalyst is 
the lowest reactor temperature determined in paragraph (b) of this 
section below which vanadium emissions are less than the method 
detection limit.



Sec.  1065.1119  Blank testing.

    This section describes the process for analyzing blanks. Use blanks 
to determine the background effects and the potential for contamination 
from the sampling process.
    (a) Take blanks from the same batch of alumina used for the capture 
bed.
    (b) Media blanks are used to determine if there is any contamination 
in the sample media. Analyze at least one media blank for each reactor 
aging cycle or round of testing performed under Sec.  1065.1117. If your 
sample media is taken from the same lot, you may analyze media blanks 
less frequently consistent with good engineering judgment.
    (c) Field blanks are used to determine if there is any contamination 
from environmental exposure of the sample media. Analyze at least one 
field blank for each reactor aging cycle or round of testing performed 
under

[[Page 305]]

Sec.  1065.1117. Field blanks must be contained in a sealed environment 
and accompany the reactor sampling system throughout the course of a 
test, including reactor disassembly, sample packaging, and storage. Use 
good engineering judgment to determine how frequently to generate field 
blanks. Keep the field blank sample close to the reactor during testing.
    (d) Reactor blanks are used to determine if there is any 
contamination from the sampling system. Analyze at least one reactor 
blank for each reactor aging cycle or round of testing performed under 
Sec.  1065.1117.
    (1) Test reactor blanks with the reactor on and operated identically 
to that of a catalyst test in Sec.  1065.1117 with the exception that 
when loading the reactor, only the alumina capture bed will be loaded 
(no catalyst sample is loaded for the reactor blank). We recommend 
acquiring reactor blanks with the reactor operating at average test 
temperature you used when acquiring your test samples under Sec.  
1065.1117.
    (2) You must run at least three reactor blanks if the result from 
the initial blank analysis is above the detection limit of the method, 
with additional blank runs based on the uncertainty of the reactor blank 
measurements, consistent with good engineering judgment.



Sec.  1065.1121  Vanadium sample dissolution and analysis in alumina capture beds.

    This section describes the process for dissolution of vanadium from 
the vanadium sublimation samples collect in Sec.  1065.1117 and any 
blanks collected in Sec.  1065.1119 as well as the analysis of the 
digestates to determine the mass of vanadium emitted and the associated 
sublimation temperature threshold based on the results of all the 
samples taken during the reactor aging cycle.
    (a) Digest the samples using the following procedure, or an 
equivalent procedure:
    (1) Place the recovered alumina, a portion of the ground quartz tube 
from the reactor, and the quartz wool in a Teflon pressure vessel with a 
mixture made from 1.5 mL of 16 N HNO3, 0.5 mL of 28 N HF, and 
0.2 mL of 12 N HCl. Note that the amount of ground quartz tube from the 
reactor included in the digestion can influence the vanadium 
concentration of both the volatilized vanadium from the sample and the 
method detection limit. You must be consistent with the amount ground 
quartz tube included in the sample analysis for your testing. You must 
limit the amount of quartz tube to include only portions of the tube 
that would be likely to encounter volatilized vanadium.
    (2) Program a microwave oven to heat the sample to 180 [deg]C over 9 
minutes, followed by a 10-minute hold at that temperature, and 1 hour of 
ventilation/cooling.
    (3) After cooling, dilute the digests to 30 mL with high purity 
18M[Omega] water prior to ICP-MS (or ICP-OES) analysis. Note that this 
digestion technique requires adequate safety measures when working with 
HF at high temperature and pressure. To avoid ``carry-over'' 
contamination, rigorously clean the vessels between samples as described 
in ``Microwave digestion procedures for environmental matrixes'' (Lough, 
G.C. et al, Analyst. 1998, 123 (7), 103R-133R).
    (b) Analyze the digestates for vanadium as follows:
    (1) Perform the analysis using ICP-OES (or ICP-MS) using standard 
plasma conditions (1350 W forward power) and a desolvating 
microconcentric nebulizer, which will significantly reduce oxide- and 
chloride-based interferences.
    (2) We recommend that you digest and analyze a minimum of three 
solid vanadium NIST Standard Reference Materials in duplicate with every 
batch of 25 vanadium alumina capture bed samples that you analyze in 
this section, as described in ``Emissions of metals associated with 
motor vehicle roadways'' (Herner, J.D. et al, Environmental Science and 
Technology. 2005, 39, 826-836). This will serve as a quality assurance 
check to help gauge the relative uncertainties in each measurement, 
specifically if the measurement errors are normally distributed and 
independent.
    (3) Use the 3-sigma approach to determine the analytical method 
detection limits for vanadium and the 10-sigma

[[Page 306]]

approach if you determine the reporting limit. This process involves 
analyzing at least seven replicates of a reactor blank using the 
analytical method described in paragraphs (a) and (b)(1) of this 
section, converting the responses into concentration units, and 
calculating the standard deviation. Determine the detection limit by 
multiplying the standard deviation by 3 and adding it to the average. 
Determine the reporting limit by multiplying the standard deviation by 
10 and adding it to the average. Determine the following analytical 
method detection limits:
    (i) Determine the ICP-MS (or ICP-OES) instrumental detection limit 
(ng/L) by measuring at least seven blank samples made up of the reagents 
from paragraph (a) of this section.
    (ii) Determine the method detection limit ([micro]g/m\3\ of flow) by 
measuring at least seven reactor blank samples taken as described in 
Sec.  1065.1119(d).
    (iii) We recommend that your method detection limit determined under 
paragraph (b)(3)(ii) of this section is at or below 15 [micro]g/m\3\. 
You must report your detection limits determined in this paragraph 
(b)(3) and reporting limits (if determined) with your test results.
    (4) If you account for vanadium-loaded particles contaminating 
catalyst-coated monoliths as a result of physical abrasion as allowed in 
Sec.  1065.1115(f), use the 3-sigma approach to determine the analytical 
method detection limits for titanium and the 10-sigma approach if you 
determine the reporting limit. This process involves analyzing at least 
seven replicates of a blank using the analytical method described in 
paragraphs (a) and (b)(1) of this section, converting the responses into 
concentration units, and calculating the standard deviation. Determine 
the detection limit by multiplying the standard deviation by 3 and 
subtracting it from the average. Determine the reporting limit by 
multiplying the standard deviation by 10 and subtracting it from the 
average.
    (i) Determine the ICP-MS (or ICP-OES) instrumental detection limit 
(ng/L) by measuring at least seven blank samples made up of the reagents 
from paragraph (a) of this section.
    (ii) Determine the method detection limit ([micro]g/m\3\ of flow) by 
measuring at least seven reactor blank samples taken as described in 
Sec.  1065.1119(d).

                              Smoke Opacity

    Source: Sections 1065.1123 through 1065.1127 appear at 88 FR 4693, 
Jan. 24, 2023, unless otherwise noted.



Sec.  1065.1123  General provisions for determining exhaust opacity.

    The provisions of Sec.  1065.1125 describe system specifications for 
measuring percent opacity of exhaust for all types of engines. The 
provisions of Sec.  1065.1127 describe how to use such a system to 
determine percent opacity of engine exhaust for applications other than 
locomotives. See 40 CFR 1033.525 for measurement procedures for 
locomotives.



Sec.  1065.1125  Exhaust opacity measurement system.

    Smokemeters measure exhaust opacity using full-flow open-path light 
extinction with a built-in light beam across the exhaust stack or plume. 
Prepare and install a smokemeter system as follows:
    (a) Except as specified in paragraph (d) of this section, use a 
smokemeter capable of providing continuous measurement that meets the 
following specifications:
    (1) Use an incandescent lamp with a color temperature between (2800 
and 3250) K or a different light source with a spectral peak between 
(550 and 570) nm.
    (2) Collimate the light beam to a nominal diameter of 3 centimeters 
and maximum divergence angle of 6 degrees.
    (3) Include a photocell or photodiode as a detector. The detector 
must have a maximum spectral response between (550 and 570) nm, with 
less than 4 percent of that maximum response below 430 nm and above 680 
nm. These specifications correspond to visual perception with the human 
eye.
    (4) Use a collimating tube with an aperture that matches the 
diameter of the light beam. Restrict the detector to viewing within a 16 
degree included angle.

[[Page 307]]

    (5) Optionally use an air curtain across the light source and 
detector window to minimize deposition of smoke particles, as long as it 
does not measurably affect the opacity of the sample.
    (6) The diagram in the following figure illustrates the smokemeter 
configuration:

   Figure 1 to paragraph (a)(6) of Sec.  1065.1125--Smokemeter Diagram
[GRAPHIC] [TIFF OMITTED] TR24JA23.142

    (b) Smokemeters for locomotive applications must have a full-scale 
response time of 0.5 seconds or less. Smokemeters for locomotive 
applications may attenuate signal responses with frequencies higher than 
10 Hz with a separate low-pass electronic filter that has the following 
performance characteristics:
    (1) Three decibel point: 10 Hz.
    (2) Insertion loss: (0.0 0.5) dB.
    (3) Selectivity: 12 dB down at 40 Hz minimum.
    (4) Attenuation: 27 dB down at 40 Hz minimum.
    (c) Configure exhaust systems as follows for measuring exhaust 
opacity:
    (1) For locomotive applications:
    (i) Optionally add a stack extension to the locomotive muffler.
    (ii) For in-line measurements, the smokemeter is integral to the 
stack extension.
    (iii) For end-of-line measurements, mount the smokemeter directly at 
the end of the stack extension or muffler.
    (iv) For all testing, minimize distance from the optical centerline 
to the muffler outlet; in no case may it be more than 300 cm. The 
maximum allowable distance of unducted space upstream of the optical 
centerline is 50 cm, whether the unducted portion is upstream or 
downstream of the stack extensions.
    (2) Meet the following specifications for all other applications:
    (i) For in-line measurements, install the smokemeter in an exhaust 
pipe segment downstream of all engine components. This will typically be 
part of a laboratory configuration to route the exhaust to an analyzer. 
The exhaust pipe diameter must be constant within 3 exhaust pipe 
diameters before and after the smokemeter's optical centerline. The 
exhaust pipe diameter may not change by more than a 12-degree half-angle 
within 6 exhaust pipe diameters upstream of the smokemeter's optical 
centerline.
    (ii) For end-of-line measurements with systems that vent exhaust to 
the ambient, add a stack extension and position the smokemeter such that 
its optical centerline is (2.5 0.625) cm upstream 
of the stack extension's exit. Configure the exhaust stack and extension 
such that at least the last 60 cm is a straight pipe with a circular 
cross

[[Page 308]]

section with an approximate inside diameter as specified in the 
following table:

Table 1 to Paragraph (c)(2)(ii) of Sec.   1065.1125--Approximate Exhaust
                   Pipe Diameter Based on Engine Power
------------------------------------------------------------------------
                                                            Approximate
                   Maximum rated power                     exhaust pipe
                                                          diameter  (mm)
------------------------------------------------------------------------
kW<40...................................................              38
40<=kW<75...............................................              50
75<=kW<150..............................................              76
150<=kW<225.............................................             102
225<=kW<375.............................................             127
kW= 375......................................             152
------------------------------------------------------------------------

    (iii) For both in-line and end-of-line measurements, install the 
smokemeter so its optical centerline is (3 to 10) meters further 
downstream than the point in the exhaust stream that is farthest 
downstream considering all the following components: exhaust manifolds, 
turbocharger outlets, exhaust aftertreatment devices, and junction 
points for combining exhaust flow from multiple exhaust manifolds.
    (3) Orient the light beam perpendicular to the direction of exhaust 
flow. Install the smokemeter so it does not influence exhaust flow 
distribution or the shape of the exhaust plume. Set up the smokemeter's 
optical path length as follows:
    (i) For locomotive applications, the optical path length must be at 
least as wide as the exhaust plume.
    (ii) For all other applications, the optical path length must be the 
same as the diameter of the exhaust flow. For noncircular exhaust 
configurations, set up the smokemeter such that the light beam's path 
length is across the longest axis with an optical path length equal to 
the hydraulic diameter of the exhaust flow.
    (4) The smokemeter must not interfere with the engine's ability to 
meet the exhaust backpressure requirements in Sec.  1065.130(h).
    (5) For engines with multiple exhaust outlets, measure opacity using 
one of the following methods:
    (i) Join the exhaust outlets together to form a single flow path and 
install the smokemeter (3 to 10) m downstream of the point where the 
exhaust streams converge or the last exhaust aftertreatment device, 
whichever is farthest downstream.
    (ii) Install a smokemeter in each of the exhaust flow paths. Report 
all measured values. All measured values must comply with standards.
    (6) The smokemeter may use purge air or a different method to 
prevent carbon or other exhaust deposits on the light source and 
detector. Such a method used with end-of-line measurements may not cause 
the smoke plume to change by more than 0.5 cm at the smokemeter. If such 
a method affects the smokemeter's optical path length, follow the 
smokemeter manufacturer's instructions to properly account for that 
effect.
    (d) You may use smokemeters meeting alternative specifications as 
follows:
    (1) You may use smokemeters that use other electronic or optical 
techniques if they employ substantially identical measurement principles 
and produce substantially equivalent results.
    (2) You may ask us to approve the use of a smokemeter that relies on 
partial flow sampling. Follow the instrument manufacturer's 
installation, calibration, operation, and maintenance procedures if we 
approve your request. These procedures must include correcting for any 
change in the path length of the exhaust plume relative to the diameter 
of the engine's exhaust outlet.



Sec.  1065.1127  Test procedure for determining percent opacity.

    The test procedure described in this section applies for everything 
other than locomotives. The test consists of a sequence of engine 
operating points on an engine dynamometer to measure exhaust opacity 
during specific engine operating modes to represent in-use operation. 
Measure opacity using the following procedure:
    (a) Use the equipment and procedures specified in this part 1065.
    (b) Calibrate the smokemeter as follows:
    (1) Calibrate using neutral density filters with approximately 10, 
20, and 40 percent opacity. Confirm that the

[[Page 309]]

opacity values for each of these reference filters are NIST-traceable 
within 185 days of testing, or within 370 days of testing if you 
consistently protect the reference filters from light exposure between 
tests.
    (2) Before each test and optionally during engine idle modes, remove 
the smokemeter from the exhaust stream, if applicable, and calibrate as 
follows:
    (i) Zero. Adjust the smokemeter to give a zero response when there 
is no detectable smoke.
    (ii) Linearity. Insert each of the qualified reference filters in 
the light path perpendicular to the axis of the light beam and adjust 
the smokemeter to give a result within 1 percentage point of the named 
value for each reference filter.
    (c) Prepare the engine, dynamometer, and smokemeter for testing as 
follows:
    (1) Set up the engine to run in a configuration that represents in-
use operation.
    (2) Determine the smokemeter's optical path length to the nearest 
mm.
    (3) If the smokemeter uses purge air or another method to prevent 
deposits on the light source and detector, adjust the system according 
to the system manufacturer's instructions and activate the system before 
starting the engine.
    (4) Program the dynamometer to operate in torque-control mode 
throughout testing. Determine the dynamometer load needed to meet the 
cycle requirements in paragraphs (d)(4)(ii) and (iv) of this section.
    (5) You may program the dynamometer to apply motoring assist with 
negative flywheel torque, but only during the first 0.5 seconds of the 
acceleration events in paragraphs (d)(4)(i) and (ii) of this section. 
Negative flywheel torque may not exceed 13.6 N[middot]m.
    (d) Operate the engine and dynamometer over repeated test runs of 
the duty cycle illustrated in Figure 1 of this appendix. As noted in the 
figure, the test run includes an acceleration mode from points A through 
F in the figure, followed by a lugging mode from points I to J. Detailed 
specifications for testing apply as follows:
    (1) Continuously record opacity, engine speed, engine torque, and 
operator demand over the course of the entire test at 10 Hz; however, 
you may interrupt measurements to recalibrate during each idle mode.
    (2) Precondition the engine by operating it for 10 minutes at 
maximum mapped power.
    (3) Operate the engine for (5.0 to 5.5) minutes at warm idle speed, 
[fnof]nidle, with load set to Curb Idle Transmission Torque.
    (4) Operate the engine and dynamometer as follows during the 
acceleration mode:
    (i) First acceleration event--AB. Partially increase and hold 
operator demand to stabilize engine speed briefly at (200 50) r/min above [fnof]nidle. The start of 
this acceleration is the start of the test (t = 0 s).
    (ii) Second acceleration event--CD. As soon as measured engine speed 
is within the range specified in paragraph (d)(4)(i) of this section, 
but not more than 3 seconds after the start of the test, rapidly set and 
hold operator demand at maximum. Operate the dynamometer using a 
preselected load to accelerate engine speed to 85 percent of maximum 
test speed, [fnof]ntest, in (5 1.5) 
seconds. The engine speed throughout the acceleration must be within 
100 r/min of a target represented by a linear 
transition between the low and high engine speed targets.
    (iii) Transition--DEF. As soon as measured engine speed reaches 85 
percent of [fnof]ntest, rapidly set and hold operator demand 
at minimum and simultaneously apply a load to decelerate to intermediate 
speed in (0.5 to 3.5) seconds. Use the same load identified for the 
acceleration event in paragraph (d)(4)(iv) of this section.
    (iv) Third acceleration event--FGH. Rapidly set and hold operator 
demand at maximum when the engine is within 50 r/
min of intermediate speed. Operate the dynamometer using a preselected 
load to accelerate engine speed to at least 95 percent of 
[fnof]ntest in (10 2) seconds.
    (5) Operate the engine and dynamometer as follows during the lugging 
mode:
    (i) Transition--HI. When the engine reaches 95 percent of 
[fnof]ntest, keep operator demand at maximum and immediately 
set dynamometer load to control the engine at maximum mapped

[[Page 310]]

power. Continue the transition segment for (50 to 60) seconds. For at 
least the last 10 seconds of the transition segment, hold engine speed 
within 50 r/min of [fnof]ntest and 
power at or above 95 percent of maximum mapped power. Conclude the 
transition by increasing dynamometer load to reduce engine speed as 
specified in paragraph (d)(4)(iii) of this section, keeping operator 
demand at maximum.
    (ii) Lugging--IJ. Apply dynamometer loading as needed to decrease 
engine speed from 50 r/min below fntest to intermediate speed 
in (35 5) seconds. The engine speed must remain 
within 100 r/min of a target represented by a 
linear transition between the low and high engine speed targets.
    (6) Return the dynamometer and engine controls to the idle position 
described in paragraph (d)(3) of this section within 60 seconds of 
completing the lugging mode.
    (7) Repeat the procedures in paragraphs (d)(3) through (6) of this 
section as needed to complete three valid test runs. If you fail to meet 
the specifications during a test run, continue to follow the specified 
duty cycle before starting the next test run.
    (8) Shut down the engine or remove the smokemeter from the exhaust 
stream to verify zero and linearity. Void the test if the smokemeter 
reports more than 2 percent opacity for the zero verification, or if the 
smokemeter's error for any of the linearity checks specified in 
paragraph (b)(2) of this section is more than 2 percent.
    (e) Analyze and validate the test data as follows:
    (1) Divide each test run into test segments. Each successive test 
segment starts when the preceding segment ends. Identify the test 
segments based on the following criteria:
    (i) The idle mode specified in paragraph (d)(3) of this section for 
the first test run starts immediately after engine preconditioning is 
complete. The idle mode for later test runs must start within 60 seconds 
after the end of the previous test run as specified in paragraph (d)(6) 
of this section. The idle mode ends when operator demand increases for 
the first acceleration event (Points A and B).
    (ii) The first acceleration event in paragraph (d)(4)(i) of this 
section ends when operator demand is set to maximum for the second 
acceleration event (Point C).
    (iii) The second acceleration event in paragraph (d)(4)(ii) of this 
section ends when the engine reaches 85 percent of maximum test speed, 
[fnof]ntest, (Point D) and operator demand is set to minimum 
(Point E).
    (iv) The transition period in paragraph (d)(4)(iii) of this section 
ends when operator demand is set to maximum (Point F).
    (v) The third acceleration event in paragraph (d)(4)(iv) of this 
section ends when engine speed reaches 95 percent of 
[fnof]ntest (Point H).
    (vi) The transition period in paragraph (d)(5)(i) of this section 
ends when engine speed first decreases to a point more than 50 r/min 
below [fnof]ntest (Point I).
    (vii) The lugging mode in paragraph (d)(5)(ii) of this section ends 
when the engine reaches intermediate speed (Point J).
    (2) Convert measured instantaneous values to standard opacity 
values, [kappa]std, based on the appropriate optical path 
length specified in Table 1 of Sec.  1065.1125 using the following 
equation:
[GRAPHIC] [TIFF OMITTED] TR24JA23.143

Where:

[kappa]std = standard instantaneous percent opacity.
[kappa]meas = measured instantaneous percent opacity.

[[Page 311]]

lstd = standard optical path length corresponding with engine 
          power, in millimeters.
lmeas = the smokemeter's optical path length, in millimeters.

                     Example for an engine < 40 kW:

[kappa]meas = 14.1%
lstd = 38 mm
lmeas = 41 mm
[GRAPHIC] [TIFF OMITTED] TR24JA23.144

    (3) Select opacity results from corrected measurements collected 
across test segments as follows:
    (i) Divide measurements from acceleration and lugging modes into 
half-second intervals. Determine average opacity values during each 
half-second interval.
    (ii) Identify the 15 highest half-second values during the 
acceleration mode of each test run.
    (iii) Identify the five highest half-second values during the 
lugging mode of each test run.
    (iv) Identify the three overall highest values from paragraphs 
(e)(3)(ii) and (iii) of this section for each test run.
    (f) Determine percent opacity as follows:
    (1) Acceleration. Determine the percent opacity for the acceleration 
mode by calculating the average of the 45 readings from paragraph 
(e)(3)(ii) of this section.
    (2) Lugging. Determine the percent opacity for the lugging mode by 
calculating the average of the 15 readings from paragraph (e)(3)(iii) of 
this section.
    (3) Peak. Determine the percent opacity for the peaks in either 
acceleration or lugging mode by calculating the average of the 9 
readings from paragraph (e)(3)(iv) of this section.
    (g) Submit the following information in addition to what is required 
by Sec.  1065.695:
    (1) Exhaust pipe diameter(s).
    (2) Measured maximum exhaust system backpressure over the entire 
test.
    (3) Most recent date for establishing that each of the reference 
filters from paragraph (b) of this section are NIST-traceable.
    (4) Measured smokemeter zero and linearity values after testing.
    (5) 10 Hz data from all valid test runs.
    (h) The following figure illustrates the dynamometer controls and 
engine speeds for exhaust opacity testing:

Figure 1 to paragraph (h) of Sec.  1065.1127--Schemati of Smoke Opacity 
                               Duty Cycle

[[Page 312]]

[GRAPHIC] [TIFF OMITTED] TR24JA23.145


[[Page 313]]



                    Accelerated Aftertreatment Aging

    Source: Sections 1065.1131 through 1065.1145 appear at 88 FR 4697, 
Jan. 24, 2023, unless otherwise noted.



Sec.  1065.1131  General provisions related to accelerated aging 
of compression-ignition aftertreatment for deterioration factor
determination.

    Sections 1065.1131 through 1065.1145 specify procedures for aging 
compression-ignition engine aftertreatment systems in an accelerated 
fashion to produce an aged aftertreatment system for durability 
demonstration. Determine the target number of hours that represents 
useful life for an engine family as described in the standard setting 
part. The method described is a procedure for translating field data 
that represents a given application into an accelerated aging cycle for 
that specific application, as well as methods for carrying out aging 
using that cycle. The procedure is intended to be representative of 
field aging, includes exposure to elements of both thermal and chemical 
aging, and is designed to achieve an acceleration of aging that is ten 
times a dynamometer or field test (1,000 hours of accelerated aging is 
equivalent to 10,000 hours of standard aging).
    (a) Development of an application-specific accelerated aging cycle 
generally consists of the following steps:
    (1) Gathering and analysis of input field data.
    (2) Determination of key components for aging.
    (3) Determination of a thermal deactivation coefficient for each key 
component.
    (4) Determination of potential aging modes using clustering 
analysis.
    (5) Down-selection of final aging modes.
    (6) Incorporation of regeneration modes (if necessary).
    (7) Cycle generation.
    (8) Calculation of thermal deactivation.
    (9) Cycle scaling to reach thermal deactivation.
    (10) Determination of oil exposure rates.
    (11) Determination of sulfur exposure rates.
    (b) There are two methods for using field data to develop aging 
cycles, as described in Sec.  1065.1139(b)(1) and (2). Method selection 
depends on the type of field data available. Method 1 directly uses 
field data to generate aging modes, while Method 2 uses field data to 
weight appropriate regulatory duty cycles that are used for emissions 
certification.
    (c) Carry out accelerated aging on either a modified engine platform 
or a reactor-based burner platform. The requirements for these platforms 
are described in Sec.  1065.1141 for engine bench aging and Sec.  
1065.1143 for burner-based bench aging.



Sec.  1065.1133  Application selection, data gathering, and analysis.

    This section describes the gathering and analysis of the field 
generated data that is required for generation of the data cycle. Gather 
data for the determination of aftertreatment exposure to thermal, 
lubricating oil, and sulfur related aging factors. You are not required 
to submit this data as part of your application, but you must make this 
data available if we request it.
    (a) Field data target selection. Use good engineering judgment to 
select one or more target applications for gathering of input field data 
for the accelerated aging cycle generation that represent a greater than 
average exposure to potential field aging factors. It should be noted 
that the same application may not necessarily represent the worst case 
for all aging factors. If sufficient data is not available to make this 
determination with multiple applications, you may select the application 
that is expected to have the highest sales volume for a given engine 
family.
    (1) Thermal exposure. We recommend that you select applications for 
a given engine family that represent the 90th percentile of exposure to 
thermal aging. For example, if a given engine family incorporates a 
periodic infrequent regeneration event that involves exposure to higher 
temperatures than are observed during normal (non-regeneration) 
operation, we recommend that you select an application wherein the total 
duration of the cumulative regeneration events is at the 90th percentile

[[Page 314]]

of expected applications for that family. For an engine that does not 
incorporate a distinct regeneration event, we recommend selecting an 
application that represents the 90th percentile in terms of the overall 
average temperature.
    (2) Oil exposure. Use a combination of field and laboratory 
measurements to determine an average rate of oil consumption in grams 
per hour that reaches the exhaust. You may use the average total oil 
consumption rate of the engine if you are unable to determine what 
portion of the oil consumed reaches the exhaust aftertreatment.
    (3) Sulfur exposure. The total sulfur exposure is the sum of fuel- 
and oil-related sulfur. Oil-related sulfur will be accounted for in the 
acceleration of oil exposure directly. We recommend that you determine 
fuel-related sulfur exposure by selecting an application that represents 
the 90th percentile of fuel consumption. Use good engineering judgment 
to determine that average rate of fuel consumption for the target 
application. You may use a combination of field and laboratory 
measurements to make this determination. Calculate the average rate of 
fuel-related sulfur exposure in grams per hour from the average rate of 
fuel consumption assuming a fuel sulfur level of 10 ppm by weight.
    (b) Application data gathering. Use good engineering judgment to 
gather data from one or more field vehicles to support the accelerated 
aging cycle generation. We recommend that you gather data at a recording 
frequency of 1 Hz. The type of data that you gather will depend on the 
method you plan to use for cycle generation. Record both the data and 
the number of engine operating hours which that data represents 
regardless of method, as this information will be used to scale the 
cycle calculations. Use good engineering judgment to ensure that the 
amount of data recorded provides an accurate representation of field 
operation for the target application. If your application includes a 
periodic regeneration event, you must record multiple events to ensure 
that you have accurately captured the variation of those events. We 
recommend that you record at least 300 hours of field operation, and at 
least 3 different regeneration events if applicable.
    (1) When using Method 1, direct field data use, as described in 
Sec.  1065.1139(b)(1), record data for exhaust flow rate and at least 
one representative inlet temperature for each major aftertreatment 
system catalyst component, such as a diesel oxidation catalyst (DOC), 
diesel particulate filter (DPF), or selective catalytic reduction (SCR) 
catalyst. If a given catalyst component has multiple substrates 
installed directly in sequence, it is sufficient to record only the 
inlet temperature for the first catalyst substrate in the sequence. It 
is not necessary to record separate temperatures for substrates that are 
``zone-coated'' with multiple catalyst functions. Record a 
representative outlet temperature for any major catalyst component that 
is used to elevate the temperature of downstream components. This could 
be the inlet of the next major component if that would be 
representative. We recommend that you record engine fuel rate to assist 
in the determination of sulfur exposure rates, but you may use other 
data for this purpose.
    (2) When using Method 2, weighting of certification cycles, as 
described Sec.  1065.1139(b)(2), record data for engine speed and engine 
load. Record sufficient ECM load parameters to determine a torque value 
that can be compared directly to engine torque as measured in the 
laboratory. You may optionally use ECM fuel rate measurements to 
determine load, but only if the same measurements can also be performed 
during laboratory testing on certification test cycles using sensors 
with comparable response characteristics. For example, you could use ECM 
fuel consumption rates for both field data and during laboratory tests.
    (i) Optionally, as an alternative to the parameters required in this 
paragraph (b)(2), you may use a system exhaust temperature measurement 
to represent load. This requires one recorded temperature that 
represents the aftertreatment system. We recommend that you use a 
temperature recorded at the outlet of the first major catalyst 
component. If you choose to use this

[[Page 315]]

option, you must use the same temperature sensor for both field and 
laboratory measurements. Do not compare measurements between on-engine 
production temperature sensors with laboratory temperature sensors.
    (ii) Optionally, as an alternative to the parameters required in 
this paragraph (b)(2), you may use exhaust flow and temperature 
measurements recorded in the field to support Method 2 calculations. 
Only one recorded temperature that represents the aftertreatment system 
is needed in this case. We recommend that you use a temperature recorded 
at the outlet of the first major catalyst component. Do not compare 
measurements between on-engine production temperature sensors with 
laboratory temperature sensors.
    (3) If you have an aftertreatment system which involves periodic 
regeneration events where the temperature is raised above levels 
observed during normal operation, you must record data to characterize 
each such event. Data must be recorded at a frequency of at least 1 Hz, 
and you must record the exhaust flow rate and inlet temperature of each 
key catalyst component that will experience elevated temperatures during 
the regeneration. In addition, record a flag or variable that can be 
used to determine the beginning and end of a regeneration event. You 
must record at least three such events to allow determination of the 
average regeneration profile. If you have multiple types of regeneration 
events which influence different catalyst components in the system, you 
must record this data for each type of event separately. Use good 
engineering judgment to determine the average duration of each type of 
regeneration event, and the average interval of time between successive 
regeneration events of that type. You may use the data recorded for this 
cycle determination, or any other representative data to determine 
average regeneration duration or regeneration interval. These values may 
be determined from the analysis used to determine emission adjustments 
to account for infrequent regeneration of aftertreatment devices in 
Sec.  1065.680.



Sec.  1065.1135  Determination of key aftertreatment system components.

    Most compression-ignition engine aftertreatment systems contain 
multiple catalysts, each with their own aging characteristics. However, 
in the accelerated aging protocol the system will be aged as a whole. 
Therefore, it is necessary to determine which catalyst components are 
the key components that will be used for deriving and scaling the aging 
cycle.
    (a) The primary aging catalyst in an aftertreatment system is the 
catalyst that is directly responsible for the majority of NOX 
reduction, such as a urea SCR catalyst in a compression ignition 
aftertreatment system. This catalyst will be used as the basis for cycle 
generation. If a system contains multiple SCR catalysts that are 
separated by other heat generating components that would result in a 
different rate of heat exposure, then each SCR catalyst must be tracked 
separately. Use good engineering judgment to determine when there are 
multiple primary catalyst components. An example of this would be a 
light-off SCR catalyst placed upstream of a DOC which is used to 
generate heat for regeneration and is followed by a DPF and a second 
downstream SCR catalyst. In this case, both the light-off SCR and the 
downstream SCR would have very different thermal history, and therefore 
must be tracked separately. In applications where there is no SCR 
catalyst in the aftertreatment system, the primary catalyst is the first 
oxidizing catalyst component in the system which is typically a DOC or 
catalyzed DPF.
    (b) The secondary aging catalyst in an aftertreatment system is the 
catalyst that is intended to either alter exhaust characteristics or 
generate elevated temperature upstream of the primary catalyst. An 
example of a secondary component catalyst would be a DOC placed upstream 
of an SCR catalyst, with or without a DPF in between.



Sec.  1065.1137  Determination of thermal reactivity coefficient.

    This section describes the method for determining the thermal 
reactivity coefficient(s) used for thermal heat load

[[Page 316]]

calculation in the accelerated aging protocol.
    (a) The calculations for thermal degradation are based on the use of 
an Arrhenius rate law function to model cumulative thermal degradation 
due to heat exposure. Under this model, the thermal aging rate constant, 
k, is an exponential function of temperature which takes the form shown 
in the following equation:
[GRAPHIC] [TIFF OMITTED] TR24JA23.146

Where:

A = frequency factor or pre-exponential factor.
Ea = thermal reactivity coefficient in kJ/mol.
R = molar gas constant.
T = catalyst temperature in K.

    (b) The process of determining Ea begins with determining 
what catalyst characteristic will be tracked as the basis for measuring 
thermal deactivation. This metric varies for each type of catalyst and 
may be determined from the experimental data using good engineering 
judgment. We recommend the following metrics; however, you may also use 
a different metric based on good engineering judgment:
    (1) Copper-based zeolite SCR. Total ammonia storage capacity is a 
key aging metric for copper-zeolite SCR catalysts, and they typically 
contain multiple types of storage sites. It is typical to model these 
catalysts using two different storage sites, one of which is more active 
for NOX reduction, as this has been shown to be an effective 
metric for tracking thermal aging. In this case, the recommended aging 
metric is the ratio between the storage capacity of the two sites, with 
more active site being in the denominator.
    (2) Iron-based zeolite SCR. Total ammonia storage capacity is a key 
aging metric for iron-zeolite SCR catalysts using a single storage site 
at 250 [deg]C for tracking thermal aging.
    (3) Vanadium SCR. Vanadium-based SCR catalysts do not feature a high 
level of ammonia storage like zeolites, therefore NOX 
reduction efficiency at lower temperatures in the range of 250 [deg]C is 
the recommended metric for tracking thermal aging.
    (4) Diesel oxidation catalysts. Conversion rate of NO to 
NO2 at 200 [deg]C is the key aging metric for tracking 
thermal aging for DOCs which are used to optimize exhaust 
characteristics for a downstream SCR system. HC reduction efficiency (as 
measured using ethylene) at 200 [deg]C is the key aging metric for DOCs 
which are part of a system that does not contain an SCR catalyst for 
NOX reduction. This same guidance applies to an oxidation 
catalyst coated onto the surface of a DPF, if there is no other DOC in 
the system.
    (c)(1) Use good engineering judgment to select at least three 
different temperatures to run the degradation experiments at. We 
recommend selecting these temperatures to accelerated thermal 
deactivation such that measurable changes in the aging metric can be 
observed at multiple time points over the course of no more than 50 
hours. Avoid temperatures that are too high to prevent rapid catalyst 
failure by a mechanism that does not represent normal aging. An example 
of temperatures to run the degradation experiment at for a small-pore 
copper zeolite SCR catalyst is 600 [deg]C, 650 [deg]C, and 725 [deg]C.
    (2) For each temperature selected, perform testing to assess the 
aging metric at different times. These time intervals do not need to be 
evenly spaced and it is typical to run these experiments using 
increasing time intervals (e.g., after 2, 4, 8, 16, and 32 hours). Use 
good engineering judgment to stop each temperature experiment after 
sufficient data has been generated to characterize the shape of the 
deactivation behavior at a given temperature.
    (d) Generate a fit of the deactivation data generated in paragraph 
(b) of this

[[Page 317]]

section at each temperature using the generalized deactivation equation:

    [GRAPHIC] [TIFF OMITTED] TR24JA23.147
    
Where:

[Omega] = aging metric.
k = thermal aging rate constant for a given temperature.
[Omega]EQ = aging metric at equilibrium (set to 0 unless 
          there is a known activity minimum).
m = model order (the model order should be set at the lowest value that 
          best fits the data at all temperatures, minimum = 1).

    (e) Using the data pairs of temperature and thermal aging rate 
constant, k, from paragraph (c)(2) of this section, determine the 
thermal reactivity coefficient, Ea, by performing a 
regression analysis of the natural log of k versus the inverse of 
temperature, T, in Kelvin. Determine Ea from the slope of the 
resulting line using the following equation:

    [GRAPHIC] [TIFF OMITTED] TR24JA23.148
    
Where:

m = the slope of the regression line of ln(k) versus 1/T.
R = molar gas constant.



Sec.  1065.1139  Aging cycle generation.

    Generation of the accelerated aging cycle for a given application 
involves analysis of the field data to determine a set of aging modes 
that will represent that field operation. There are two methods of cycle 
generation, each of which is described separately below. Method 1 
involves the direct application of field data and is used when the 
recorded data includes sufficient exhaust flow and temperature data to 
allow for determination of aging conditions directly from the field data 
set and must be available for all of the key components. Method 2 is 
meant to be used when insufficient flow and temperature data is 
available from the field data. In Method 2, the field data is used to 
weight a set of modes derived from the laboratory certification cycles 
for a given application. These weighted modes are then combined with 
laboratory recorded flow and temperatures on the certification cycles to 
derive aging modes. There are two different cases to consider for aging 
cycle generation, depending on whether or not a given aftertreatment 
system incorporates the use of a periodic regeneration event. For the 
purposes of this section, a ``regeneration'' is any event where the 
operating temperature of some part of the aftertreatment system is 
raised beyond levels that are observed during normal (non-regeneration) 
operation. The analysis of regeneration data is considered separately 
from normal operating data.
    (a) Cycle generation process overview. The process of cycle 
generation begins with the determination of the number of bench aging 
hours. The input into this calculation is the number of real or field 
hours that represent the useful life for the target application. This 
could be given as a number of hours or miles, and for miles, the 
manufacturer must use field data and good engineering judgment to 
translate this to an equivalent number of operating hours

[[Page 318]]

for the target application. The target for the accelerated aging 
protocol is a 10-time acceleration of the aging process, therefore the 
total number of aging hours is always set at useful life hours divided 
by 10. For example, if an on-highway heavy duty engine has a full useful 
life of 750,000 miles and this is determined to be represented by 24,150 
field hours, the target duration for the DAAAC protocol for this 
application would be 2,415 bench-aging hours. The 2,415 hours will then 
be divided among different operating modes that will be arranged to 
result in repetitive temperature cycling over that period. For systems 
that incorporate periodic regeneration, the total duration will be split 
between regeneration and normal (non-regeneration) operation. The 
analysis of normal operation data is given in paragraph (b) of this 
section. The analysis of regeneration data is given in paragraph (c) of 
this section.
    (b) Analysis of normal (non-regeneration) operating data. This 
analysis develops a reduced set of aging modes that represent normal 
operation. As noted earlier, there are two methods for conducting this 
analysis, based on the data available.
    (1) Method 1--Direct clustering. Use Method 1 when sufficient 
exhaust flow and temperature data are available directly from the field 
data. The data requirements for Method 1 are described in Sec.  
1065.1133(b)(1). The method involves three steps: clustering analysis, 
mode consolidation, and cycle building.
    (i) The primary method for determining modes from a field data set 
involves the use of k-means clustering. K-means clustering is a method 
where a series of observations is partitioned into set of clusters of 
``similar'' data points, where every observation is a member of a 
cluster with the nearest mean, which is referred to as the centroid of 
that cluster. The number of clusters is a parameter of the analysis, and 
the k-means algorithm generally seeks an optimal number of clusters to 
minimize the least-squares distance of all points to their respective 
centroids. There are a number of different commercially available 
software programs to perform k-means clustering, as well as freely 
available algorithm codes. K-means clustering can arrive at many 
different solutions, and we are providing the following guidance to help 
select the optimal solution for use in accelerated aging cycle 
generation. The process involves analyzing the data multiple time using 
an increasing number of clusters for each analysis. Use at least 5 
clusters, and we recommend developing solutions for the range between 5 
and 8 clusters, although you may use more if desired. Each cluster is a 
potential aging mode with a temperature and flow rate defined by the 
centroid. More clusters result in more aging modes, although this number 
may be reduced later via model consolidation.
    (ii) The cubic clustering criteria (CCC) is a metric calculated for 
each solution having a different number of clusters. The computation of 
CCC is complex and described in more detail in the following reference. 
The CCC computation is normally available as one of the metrics in 
commercially available software packages that can be used for k-means 
clustering. The optimal solution is typically the one with the number of 
clusters corresponding to the highest CCC.
    (iii) Check each solution, starting with the one with the highest 
CCC to determine if it satisfies the following requirements:
    (A) No more than one cluster contains fewer than 3% of the data 
points.
    (B) The temperature ratio between the centroid with the maximum 
temperature and the centroid with the minimum temperature is at least 
1.6 for clusters containing more than 3% of the data points.
    (C) If that solution does not satisfy these requirements move to the 
solution with the next highest CCC.
    (iv) The process described in paragraph (c)(1)(iii) of this section 
generally works well for most data sets, but if you have difficulty with 
the CCC metric in a particular data set, use good engineering judgment 
to leverage additional criteria to help the down-selection process. 
Examples of alternate clustering metrics include a Davies-Bouldin Index 
(optimizing on the minimum value) or a Calinski-Harabasz Index (optimize 
on the maximum value).

[[Page 319]]

    (v) The initial candidate mode conditions are temperature and flow 
rate combinations that are the centroids for each cluster from the 
analysis in paragraph (c)(1)(iii) of this section. As part of the 
analysis, you must also determine the 10th percentile and 90th 
percentile temperatures for each cluster. These additional values may be 
needed later for the cycle heat load tuning process described in Sec.  
1065.1143.
    (vi) The mode weight factor for a given cluster is the fraction data 
points contained within that cluster.
    (2) Method 2--Cluster-based weighting of certification cycle modes. 
Use Method 2 if there is insufficient exhaust flow and temperature data 
from the field at the time the cycle is being developed. The data 
requirements for Method 2 are described in Sec.  1065.1133(b)(2). You 
also need laboratory data recorded in the form of 1 Hz data sets for the 
regulatory duty cycles you are certifying to for your application as 
described in the standard setting part. Include exhaust flow rate and 
the inlet temperature for each key catalyst component in the laboratory 
data sets, as described in paragraph (e) of this section. The laboratory 
data sets must also include parameters that match the field data as 
described in Sec.  1065.1133(b)(2), which will be used to facilitate the 
clustering analysis.
    (i) Perform k-means clustering is described in Sec.  1065.1133(b)(1) 
but using data sets containing the two parameters recorded in the field 
data sets. For example, you might use speed and torque, as recorded both 
in the field and the laboratory for Method 2 clustering.
    (ii) Determine the fraction of points from each of the regulatory 
laboratory duty-cycles that are within each cluster, in addition to the 
overall fraction of points from the entire data set.
    (iii) For each cycle, calculate a square sum error, SSE, as follows:
    [GRAPHIC] [TIFF OMITTED] TR24JA23.149
    
Where:

i = an indexing variable that represents one cluster.
N = total number of clusters.
Cycleprob = the fraction of points in a given cluster, i, for 
          the regulatory duty-cycle of interest.
RefDataprob = the fraction of points in a given cluster, i, 
          for the full data set.

    (iv) For each cycle, calculate a dissimilarity index as follows:
    [GRAPHIC] [TIFF OMITTED] TR24JA23.150
    
Where:

SSE = sum square error from Eq. 1065.1139-2.
Ng = total number of clusters.

    (v) If you have more than one regulatory duty cycle, weight the 
regulatory cycles.
    (A) Determine the weighting factors for a given regulatory cycle, 
wi, by solving a system of equations:

[[Page 320]]

[GRAPHIC] [TIFF OMITTED] TR24JA23.151

Where:

di = dissimilarity for a given regulatory cycle, i.
dj = dissimilarity for a given regulatory cycle, j.

    (B) For example, for three duty cycles, calculate w1 as 
follows:
[GRAPHIC] [TIFF OMITTED] TR24JA23.152

    (C) Calculate subsequent wi values after calculating 
w1 as follows:
[GRAPHIC] [TIFF OMITTED] TR24JA23.153

    (D) Calculate the sum of the weighting factors to verify that they 
are equal to one.
[GRAPHIC] [TIFF OMITTED] TR24JA23.154

Where:

n = number of regulatory cycles for the application.

    (vi) For each regulatory cycle determine the average exhaust flow 
and the average inlet temperature for each key catalyst. Determine the 
25th and 90th percentile inlet temperatures for the primary catalyst and 
the respective associated exhaust flow rate for each data point.
    (vii) Use the cycle weights from paragraph (b)(2)(v) of this section 
and the mode conditions from paragraph (b)(2)(vi) of this section to 
generate a set of candidate aging modes by multiplying the cycle weight 
factor, w[cycle] by 0.25 for the 25th percentile temperature 
mode, 0.65 for the 50th percentile temperature mode, and by 0.10 for the 
90th percentile temperature mode. This will generate a weighted set of 
mode numbers three times the number of regulatory cycles for the target 
application. Each mode will have a target temperature and exhaust flow 
rate.

[[Page 321]]

    (viii) If you have only one regulatory cycle for your application, 
use the cycle modes and weighting factors as they are given in the 
standard setting part.
    (3) Determination of mode total durations. The output for either 
method will be a set of mode exhaust conditions, with an associated 
weighting factor for each mode. Multiply the mode weight factors by the 
total number of normal operating (non-regenerating) hours, to get a 
target mode duration for each mode. This will be used in the heat load 
calculations.
    (c) Mode consolidation. Sometimes the clustering analysis process 
will generate multiple modes that are very similar to each other in 
temperature, such that although they are distinct modes they will not 
have a significantly different impact on aftertreatment aging. To reduce 
the complexity of the aging cycle, you may consolidate modes that are 
similar into a single mode as described below.
    (1) Consolidate any two or more modes which have a target 
temperature within 10 [deg]C into a single mode. If you choose to do 
this, the target temperature of the single consolidated mode is the 
temperature associated with the highest weight factor mode before 
consolidation. If the modes being consolidated all have weighting 
factors within 0.05 of each other, use the highest temperature among the 
modes.
    (2) Use the highest exhaust flow target among the modes being 
combined as the target exhaust flow for new consolidate mode.
    (3) Use the combined sum of the weighting factors for all modes 
being consolidate as the weighting factor for the new consolidated mode. 
Similarly, the total duration of the new consolidated mode is the sum of 
the durations of the modes being consolidated.
    (d) Analysis of regeneration data. Regeneration data is treated 
separately from the normal operating mode data. Generally, the target 
for accelerated aging cycle operation is to run all of the regenerations 
that would be expected over the course of useful life. If multiple types 
of regeneration are conducted on different system components, each type 
of regeneration must be analyzed separately using the steps in this 
paragraph (d). The data requirements for input into this process are 
described in Sec.  1065.1133(b)(3). The process described below is meant 
to determine a representative regeneration profile that will be used 
during aging. You may also ask us to allow the use of other engineering 
data or analysis to determine a representative regeneration profile.
    (1) The total number of regenerations that will be run during the 
accelerated aging process will be the same as the total number of 
regenerations over useful life. Calculate this number by dividing the 
total number of useful life hours by the interval between regenerations 
as determined in Sec.  1065.1133(b)(3).
    (2) Use the 1 Hz regeneration data to determine an appropriate 
regeneration profile. The recorded regeneration event begins when the 
engine indicates it has started regeneration using the recorded 
regeneration indicator and ends when the aftertreatment has returned 
back to the normal operating temperature after the flag indicates the 
regeneration is complete.
    (3) For each recorded regeneration, calculate the cumulative 
deactivation, Dt, using the equations in paragraph (e) of 
this section.
    (4) If you have a large number of recorded regenerations in your 
data set, select a regeneration event with a cumulative deactivation 
representing the 75th percentile of the distribution of heat loads in 
your recorded data set. If you have a smaller number of recorded 
regenerations, such that you cannot clearly identify the real 
distribution, select the recorded regeneration with the highest recorded 
cumulative deactivation.
    (5) This regeneration event will be used as the regeneration profile 
for that type of event during aging. The profile should include the 
entire event, include the temperature ramp and cool-down period.
    (6) The regeneration must be conducted in the same manner as it is 
run in the field. For instance, if the regeneration temperature is 
generated from an exothermic reaction by injecting

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fuel in front of a DOC, this methodology should also be used during 
bench aging.
    (7) If part of the system is at a lower temperature during 
regeneration because it is upstream of the temperature generating 
component, the set the target temperature for the aftertreatment system 
inlet to be equivalent to the system inlet temperature used during the 
highest duration non-regeneration mode, or 350 [deg]C, whichever is 
lower.
    (e) Heat load calculation and tuning for systems that have 
regeneration events. Perform this procedure after the preliminary cycles 
are completed for both normal and regeneration operation. The target 
cumulative deactivation is determined from the input field data, and 
then a similar calculation is performed for the preliminary aging cycle. 
If the cumulative deactivation for the preliminary cycle does not match 
cumulative deactivation from the field data, then the cycle is tuned 
over a series of steps until the target is matched.
    (1) The deactivation for a given catalyst is calculated for each 
time step as follows:
[GRAPHIC] [TIFF OMITTED] TR24JA23.155

Where:

Di = incremental deactivation for time step i.
Ea = thermal reactivity coefficient for the catalyst as 
          determined in Sec.  1065.1137.
R = molar gas constant in kJ/mol[middot]K.
Tstd = standard temperature = 293.15 K.
T = catalyst temperature in K.

    (2) Calculate the cumulative deactivation, Dt, for a 
given catalyst over a series of time steps, N, using the following 
equation:
[GRAPHIC] [TIFF OMITTED] TR24JA23.156

Where:

i = an indexing variable that represents one time step.
N = total number of cumulative deactivation time steps in the data set.
Di = incremental deactivation for each time step.

    (3) Calculate the cumulative deactivation, Dt, for the 
input field data set. The time step for the calculations should be 1 
second for 1-Hz input data.
    (i) First calculate Dt for the non-regeneration portion 
of the field data set. For Method 2 use the 1-Hz data from the 
regulatory cycles as the field data set.
    (ii) Divide the calculate field Dt by the number of hours 
represented in the field data set.
    (iii) Multiply the hourly Dt by the number of hours 
required to reach full useful life. This is the target 
Dt,field-normi.
    (iv) Multiply the total number of regenerations for full useful life 
by the cumulative deactivation Dt for the target regeneration 
profile determined in paragraph (d)(4) of this section. This is the 
target Dt,field-regen.
    (v) The total target cumulative deactivation for the field data, 
Dt,field, is the sum of Dt,field-normi and 
Dt,field-regen.
    (4) Calculate the cumulative deactivation for the candidate aging 
cycle generated under paragraphs (c) and (d) of this section as follows:
    (i) Using the modes and mode durations for normal operation 
generated in paragraph (c) of this section, calculate

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the cumulative deactivation, Dt,cycle-norm, using the method 
given in paragraph (e)(2) of this section.
    (ii) The total cumulative deactivation for the candidate aging 
cycle, Dt, is the sum of Dt,cycle-norm and 
Dt,field-regen.
    (5) If Dt,cycle is within 1% of 
Dt,field, the candidate cycle is deemed representative and 
may be used for aging.
    (6) If Dt,cycle is not within 1% of 
Dt,field, the candidate cycle must be adjusted to meet this 
criterion using the following steps. It should be noted that if the 
Dt,cycle is outside of the criteria it will usually be lower 
than the Dt,field.
    (i) Increase the duration of the stable portion of the regeneration 
profile, which is defined as the portion of the regeneration profile 
where the temperature has completed ramping and is being controlled to a 
stationary target temperature. Note that this will increase the number 
of hours of regeneration time. You must compensate for this by 
decreasing the total number of normal operation (non-regeneration) hours 
in the cycle. Recalculate the duration of all the normal operation 
modes. You may not increase the duration of the stable portion of the 
regeneration profile by more than a factor of 2. If you reach this limit 
and you still do not meet the criteria in paragraph (e)(5) of this 
section, proceed to the next step.
    (ii) Increase the target temperature of the stable portion of the 
regeneration profile by the amount necessary to reach the target 
criteria. You may not increase this temperature higher than the 
temperature observed in the regeneration profile with the highest 
Dt observed in the field. If you reach this limit and you 
still do not meet the criteria in paragraph (e)(5) of this section, 
proceed to the next step.
    (iii) Increase the target temperature of the highest temperature 
normal operation mode. You may not increase this temperature above the 
90th percentile determined in paragraph (b)(1)(v) of this section for 
Method 1, or above the maximum temperature for the regulatory cycle from 
which the mode was derived for Method 2. If you reach this limit and you 
still do not meet the criteria in paragraph (e)(5) of this section, you 
may repeat this step using the next highest temperature mode, until you 
reach the target, or all modes have been adjusted.
    (iv) If you are unable to reach the target deactivation by following 
paragraphs (e)(6)(i) through (iii) of this section, use good engineering 
judgment to increase the number of regenerations to meet the criteria in 
paragraph (e)(5) of this section. Note that this will increase the total 
regeneration hours, therefore you must decrease the number of normal 
operation hours and re-calculate mode durations for the normal operation 
modes.
    (f) Heat load calculation and tuning for systems that do not have 
regeneration events. Follow the steps described for systems with 
regeneration events to calculate Dt,field and 
Dt,cycle, omitting the steps related to regeneration events. 
The Dt,cycle will be well below the Dt,field. 
Follow the steps given below to adjust the cycle until you meet the 
criteria in paragraph (e)(5) of this section.
    (1) Increase the temperature of the highest temperature mode. Use 
good engineering judgment to ensure that this temperature does not 
exceed the limits of the catalyst in a way that might cause rapid 
deactivation or failure via a mechanism that is not considered normal 
degradation.
    (2) Increase the duration of the highest temperature mode and 
decrease the duration of the other modes in proportion. You may not 
increase the duration highest temperature mode by more than a factor of 
2.
    (g) Final aging cycle assembly. The final step of aging cycle 
development is the assembly of the actual cycle based on the mode data 
from either paragraph (e) of this section for systems with infrequent 
regeneration, or paragraph (f) of this section for systems that do not 
incorporate infrequent regeneration. This cycle will repeat a number of 
times until the total target aging duration has been reached.
    (1) Cycle assembly with infrequent regenerations. For systems that 
use infrequent regenerations, the number of cycle repeats is equal to 
the number of regeneration events that happen over full useful life. The 
infrequent regenerations are placed at the end of the cycle. The total 
cycle duration of the aging cycle is calculated as the total aging 
duration in hours divided by the

[[Page 324]]

number of infrequent regeneration events. In the case of systems with 
multiple types of infrequent regenerations, use the regeneration with 
the lowest frequency to calculate the cycle duration.
    (i) If you have multiple types of infrequent regenerations, arrange 
the more frequent regenerations such that they are spaced evenly 
throughout the cycle.
    (ii) Determine the length of the normal (non-regeneration) part of 
the cycle by subtracting the regeneration duration, including any 
regeneration extension determined as part of cycle tuning from paragraph 
(e) of this section, from the total cycle duration. If you have multiple 
types of regeneration, then the combined total duration of regeneration 
events performed in the cycle must be subtracted from the total. For 
example, if you have one type of regeneration that is performed for 30 
minutes every 30 cycle hours, and a second type that is performed for 30 
minutes every 10 cycle hours (such that 3 of these secondary events will 
happen during each cycle), then you would subtract a total of 2 hours of 
regeneration time from the total cycle duration considering all 4 of 
these events.
    (iii) Divide the duration of the normal part of the cycle into modes 
based on the final weighting factors determined in paragraph (c) of this 
section following any mode consolidation.
    (iv) Place the mode with the lowest temperature first, then move to 
the highest temperature mode, followed by the next lowest temperature 
mode, and then the next highest mode, continuing in this alternating 
pattern until all modes are included.
    (v) Transition between normal modes within (60 to 300) seconds. The 
transition period is considered complete when you are within 5 [deg]C of the target temperature for the primary key 
component. Transitions may follow any pattern of flow and temperature to 
reach this target within the required 300 seconds.
    (vi) For normal modes longer than 30 minutes, you may count the 
transition time as time in mode. Account for the transition time for 
modes shorter than 30 minutes by shortening the duration of the longest 
mode by an equivalent amount of time.
    (vii) If the shortest normal operating mode is longer than 60 
minutes, you must divide the normal cycle into shorter sub-cycles with 
the same pattern in paragraph (g)(1)(iii) of this section, but with 
shorter durations, so that the pattern repeats two or more times. You 
must divide the cycle into sub-cycles until the duration of the shortest 
mode in each sub-cycle is no longer than 30 minutes. No mode may have a 
duration shorter than 15 minutes, not including transition time.
    (viii) If a regeneration event is scheduled to occur during a normal 
mode, shift the start of regeneration to the end of the nearest normal 
mode.
    (2) Cycle assembly without infrequent regenerations. For systems 
that do not use infrequent regenerations, the cycle will be arranged to 
achieve as much thermal cycling as possible using the following steps.
    (i) Assign a duration of 15 minutes to the mode with the lowest 
weight factor. Calculate the duration of the remaining modes in 
proportion to the final weight factors after mode durations have been 
adjusted during heat load tuning in paragraph (f) of this section.
    (ii) Place the mode with the lowest temperature first, then move to 
the highest temperature mode, followed by the next lowest temperature 
mode, and then the next highest mode, continuing in this alternating 
pattern until all modes are included.
    (iii) Transition between normal modes within (60 to 300) seconds. 
The transition period is considered complete when you are within 5 [deg]C of the target temperature for the primary key 
component. Transitions may follow any pattern of flow and temperature to 
reach this target within the required 300 seconds.
    (iv) For normal modes longer than 30 minutes, you may count the 
transition time as time in mode. Account for the transition time for 
modes shorter than 30 minutes by shortening the duration of the longest 
mode by an equivalent amount of time.
    (v) This cycle will be repeated the number of times necessary to 
reach the target aging duration.

[[Page 325]]

    (h) Determination of accelerated oil exposure targets. The target 
oil exposure rate during accelerated aging is 10 times the field average 
oil consumption rate determined in Sec.  1065.1133(a)(2). You must 
achieve this target exposure rate on a cycle average basis during aging. 
Use good engineering judgment to determine the oil exposure rates for 
individual operating modes that will achieve this cycle average target. 
For engine-based aging stands you will likely have different oil 
consumption rates for different modes depending on the speed and load 
conditions you set. For burner-based aging stands, you may find that you 
have to limit oil exposure rates at low exhaust flow or low temperature 
modes to ensure good atomization of injected oil. On a cycle average 
basis, the portion of oil exposure from the volatile introduction 
pathway (i.e., oil doped in the burner or engine fuel) must be between 
(10 to 30)% of the total. The remainder of oil exposure must be 
introduced through bulk pathway.
    (1) Determination of accelerated fuel sulfur exposure targets. The 
target sulfur exposure rate for fuel-related sulfur is determined by 
utilizing the field mean fuel rate data for the engine determined in 
Sec.  1065.1133(a)(3). Calculate the total sulfur exposure mass using 
this mean fuel rate, the total number of non-accelerated hours to reach 
full useful life, and a fuel sulfur level of 10 ppmw.
    (i) For an engine-based aging stand, if you perform accelerated 
sulfur exposure by additizing engine fuel to a higher sulfur level, 
determine the accelerated aging target additized fuel sulfur mass 
fraction, wS, as follows:
[GRAPHIC] [TIFF OMITTED] TR24JA23.157

Where:

mifuel,field = field mean fuel flow rate.
mifuel,cycle = accelerated aging cycle mean fuel flow rate.
mSfuel,ref = reference mass of sulfur per mass of fuel = 
          0.00001 kg/kg
Sacc,rate = sulfur acceleration rate = 10

                                Example:

mifuel,field = 54.3 kg/hr
mifuel,cycle = 34.1 kg/hr
mSfuel,ref = 0.00001 kg/kg.
Sacc,rate = 10.
[GRAPHIC] [TIFF OMITTED] TR24JA23.158

wS,target = 0.000159

    (ii) If you use gaseous SO2 to perform accelerated sulfur 
exposure, such as on a burner-based stand, calculate the target 
SO2 concentration to be introduced, xSO2,target, 
as follows:
[GRAPHIC] [TIFF OMITTED] TR24JA23.159


[[Page 326]]


Where:

mifuel,field = field mean fuel flow rate.
miexhaust,cycle = mean exhaust flow rate during the burner 
          aging cycle.
xSfuel,ref = reference mol fraction of sulfur in fuel = 10 
          [micro]mol/mol.
Sacc,rate = sulfur acceleration rate = 10.
Mexh = molar mass of exhaust = molar mass of air.
MS = molar mass of sulfur.

                                Example:

mifuel,field = 54.3 kg/hr
miexhaust,cycle = 1000.8 kg/hr
xSfuel,ref = 10 [micro]mol/mol
Sacc,rate = 10
Mexh = 28.96559 g/mol
MS = 32.065 g/mol
[GRAPHIC] [TIFF OMITTED] TR24JA23.160

xSO2,target = 4.90 [micro]mol/mol

    (iii) You may choose to turn off gaseous sulfur injection during 
infrequent regeneration modes, but if you do you must increase the 
target SO2 concentration by the ratio of total aging time to 
total normal (non-regeneration) aging time.
    (2) [Reserved]



Sec.  1065.1141  Facility requirements for engine-based aging stands.

    An engine-based accelerated aging platform is built around the use 
of a compression-ignition engine for generation of heat and flow. You 
are not required to use the same engine as the target application that 
is being aged. You may use any compression-ignition engine as a bench 
aging engine, and the engine may be modified as needed to support 
meeting the aging procedure requirements. You may use the same bench 
aging engine for deterioration factor determination from multiple engine 
families. The engine must be capable of reaching the combination of 
temperature, flow, NOX, and oil consumption targets required. 
We recommend using an engine platform larger than the target application 
for a given aftertreatment system to provide more flexibility to achieve 
the target conditions and oil consumption rates. You may modify the 
bench aging engine controls in any manner necessary to help reach aging 
conditions. You may bypass some of the bench aging engine exhaust around 
the aftertreatment system being aged to reach targets, but you must 
account for this in all calculations and monitoring to ensure that the 
correct amount of oil and sulfur are reaching the aftertreatment system. 
If you bypass some of the engine exhaust around the aftertreatment 
system, you must directly measure exhaust flow rate through the 
aftertreatment system. You may dilute bench aging engine exhaust prior 
to introduction to the aftertreatment system, but you must account for 
this in all calculations and monitoring to ensure that the correct 
engine conditions and the correct amount of oil and sulfur are reaching 
the aftertreatment system. Your engine-based aging stand must 
incorporate the following capabilities:
    (a) Use good engineering judgment to incorporate a means of 
controlling temperature independent of the engine. An example of such a 
temperature control would be an air-to-air heat exchanger. The 
temperature control system must be designed to prevent condensation in 
the exhaust upstream of the aftertreatment system. This independent 
temperature control is necessary to provide the flexibility required to 
reach temperature, flow, oil consumption targets, and NOX 
targets.
    (b) Use good engineering judgment to modify the engine to increase 
oil consumption rates to levels required for accelerated aging. These 
increased oil consumption levels must be sufficient to reach the bulk 
pathway exposure targets determined in Sec.  1065.1139(h). A combination 
of engine modifications and careful operating mode selection will be 
used to reach the final bulk pathway oil exposure target on a cycle 
average. You must modify the engine

[[Page 327]]

in a fashion that will increase oil consumption in a manner such that 
the oil consumption is still generally representative of oil passing the 
piston rings into the cylinder. Use good engineering judgment to break 
in the modified engine to stabilize oil consumption rates. We recommend 
the following methods of modification (in order of preference):
    (1) Install the top compression rings inverted (upside down) on all 
the cylinders of the bench aging engine.
    (2) If the approach in paragraph (b)(1) of the section is 
insufficient to reach the targets, modify the oil control rings in one 
or more cylinders to create small notches or gaps (usually no more than 
2 per cylinder) in the top portion of the oil control rings that contact 
the cylinder liner (care must be taken to avoid compromising the 
structural integrity of the ring itself).
    (c) We recommend that the engine-aging stand include a constant 
volume oil system with a sufficiently large oil reservoir to avoid oil 
``top-offs'' between oil change intervals.
    (d) If the engine-aging stand will be used for aging of systems that 
perform infrequent regenerations, the aging stand must incorporate a 
means of increasing temperature representative of the target 
application. For example, if the target application increases 
temperature for regeneration by introducing fuel into the exhaust 
upstream of an oxidation catalyst, the aging stand must incorporate a 
similar method of introducing fuel into the exhaust.
    (e) If the engine-aging stand will be used for aging systems that 
incorporate SCR-based NOX reduction, the aging stand must 
incorporate a representative means of introducing DEF at the appropriate 
location(s).
    (f) Use good engineering judgment to incorporate a means of 
monitoring oil consumption on at least a periodic basis. You may use a 
periodic drain and weigh approach to quantify oil consumption. You must 
validate that the aging stand reaches oil consumption targets prior to 
the start of aging. You must verify oil consumption during aging prior 
to each emission testing point, and at each oil change interval. 
Validate or verify oil consumption over a running period of at least 72 
hours to obtain a valid measurement. If you do not include the constant 
volume oil system recommended in paragraph (c) of this section, you must 
account for all oil additions.
    (g) Use good engineering judgment to establish an oil change 
interval that allows you to maintain relatively stable oil consumption 
rates over the aging process. Note that this interval may be shorter 
than the normal recommended interval for the engine due to the 
modifications that have been made.
    (h) If the engine-aging stand will be used for aging of systems that 
incorporate a diesel particulate filter (DPF), we recommend you perform 
secondary tracking of oil exposure by using clean (soot free) DPF 
weights to track ash loading and compare this mass of ash to the amount 
predicted using the measured oil consumption mass and the oil ash 
concentration. The mass of ash found by DPF weight should fall within 
(55 to 70)% of the of mass predicted from oil consumption measurements.
    (i) Incorporate a means of introducing lubricating oil into the 
engine fuel to enable the volatile pathway of oil exposure. You must 
introduce sufficient oil to reach the volatile pathway oil exposure 
targets determined in paragraph (h) of this section. You must measure 
the rate of volatile pathway oil introduction on a continuous basis.
    (j) If you perform sulfur acceleration by increasing the sulfur 
level of the engine fuel, you must meet the target sulfur level within 
5 ppmw. Verify the sulfur level of the fuel prior 
to starting aging, or whenever a new batch of aging fuel is acquired.
    (k) If you use gaseous SO2 for sulfur acceleration, you 
must incorporate a means to introduce the gaseous SO2 
upstream of the aftertreatment system. Use good engineering judgment to 
ensure that gaseous SO2 is well mixed prior to entering the 
aftertreatment system. You must monitor the rate of gaseous 
SO2 introduction on a continuous basis.



Sec.  1065.1143  Requirements for burner-based aging stands.

    A burner-based aging platform is built using a fuel-fired burner as 
the

[[Page 328]]

primary heat generation mechanism. The burner must utilize diesel fuel 
and it must produce a lean exhaust gas mixture. You must configure the 
burner system to be capable of controlling temperature, exhaust flow 
rate, NOX, oxygen, and water to produce a representative 
exhaust mixture that meets the accelerated aging cycle targets for the 
aftertreatment system to be aged. You may bypass some of the bench aging 
exhaust around the aftertreatment system being aged to reach targets, 
but you must account for this in all calculations and monitoring to 
ensure that the correct amount of oil and sulfur are reaching the 
aftertreatment system. The burner system must incorporate the following 
capabilities:
    (a) Directly measure the exhaust flow through the aftertreatment 
system being aged.
    (b) Ensure transient response of the system is sufficient to meet 
the cycle transition time targets for all parameters.
    (c) Incorporate a means of oxygen and water control such that the 
burner system is able to generate oxygen and water levels representative 
of compression-ignition engine exhaust.
    (d) Incorporate a means of oil introduction for the bulk pathway. 
You must implement a method that introduces lubricating oil in a region 
of the burner that does not result in complete combustion of the oil, 
but at the same time is hot enough to oxidize oil and oil additives in a 
manner similar to what occurs when oil enters the cylinder of an engine 
past the piston rings. Care must be taken to ensure the oil is properly 
atomized and mixed into the post-combustion burner gases before they 
have cooled to normal exhaust temperatures, to insure proper digestion 
and oxidation of the oil constituents. You must measure the bulk pathway 
oil injection rate on a continuous basis. You must validate that this 
method produces representative oil products using the secondary method 
in Sec.  1065.1141(h) regardless of whether you will use the burner-
based aging stand to age systems which include a DPF. Use good 
engineering judgment to select a DPF for the initial validation of the 
system. Perform this validation when the burner-based aging stand is 
first commissioned or if any system modifications are made that affect 
the oil consumption introduction method. We also recommend that you 
examine ash distribution on the validation DPF in comparison to a 
representative engine aged DPF.
    (e) Incorporate a means of introducing lubricating oil into the 
burner fuel to enable the volatile pathway of oil exposure. You must 
introduce sufficient oil to reach the volatile pathway oil exposure 
targets determined in Sec.  1065.1139(h). You must measure the rate of 
volatile pathway oil introduction on a continuous basis.
    (f) If the burner-based aging stand will be used for aging of 
systems that perform infrequent regenerations, the aging stand must 
incorporate a means of increasing temperature representative of the 
target application. For example, if the target application increases 
temperature for regeneration by introducing fuel into the exhaust 
upstream of an oxidation catalyst, the aging stand must incorporate a 
similar method of introducing fuel into the exhaust.
    (g) If the burner-based aging stand will be used for aging of 
systems that incorporate SCR-based NOX reduction, the aging 
stand must incorporate a representative means of introducing DEF at the 
appropriate location(s).
    (h) If the burner-based aging stand will be used for aging of 
systems that incorporate a diesel particulate filter (DPF), we recommend 
you perform secondary tracking of oil exposure by using clean (soot 
free) DPF weights to track ash loading and compare this mass of ash to 
the amount predicted using the measured oil consumption mass and the oil 
ash concentration. The mass of ash found by DPF weight should fall 
within (55 to 70)% of the of mass predicted from oil consumption 
measurements.
    (i) You must incorporate a means to introduce the gaseous 
SO2 upstream of the aftertreatment system. Use good 
engineering judgment to ensure that gaseous SO2 is well mixed 
prior to entering the aftertreatment system. You must monitor the rate 
of gaseous SO2 introduction on a continuous basis.

[[Page 329]]



Sec.  1065.1145  Execution of accelerated aging, cycle tracking, 
and cycle validation criteria.

    The aging cycle generally consists first of practice runs to 
validate and tune the final cycle, followed by the actual running of the 
repeat cycles needed to accumulate field equivalent hours to reach full 
useful life. During the course of the aging run, various aging 
parameters are tracked to allow verification of proper cycle execution, 
as well as to allow for correction of the aging parameters to stay 
within the target limits.
    (a) Preliminary cycle validation runs. Prior to the start of aging, 
conduct a number of practice runs to tune the cycle parameters. It is 
recommended that initial practice runs be conducted without the 
aftertreatment installed, but with the backpressure of the 
aftertreatment simulated to help ensure that the tuned cycle is 
representative. For final cycle tuning, including regenerations, it is 
recommended to use a duplicate or spare aftertreatment system of similar 
design to the target system, to avoid damage or excessive initial aging 
during the tuning. However, it is permissible to conduct final tuning 
using the target system being aged, but you must limit the total 
duration to no more than 100 field equivalent hours (10 hours of 
accelerated aging), including both thermal and chemical components. The 
process followed for these initial runs will vary depending on whether 
you are using an engine-based platform or a burner-based platform.
    (1) Engine-based platform. (i) Initial cycle development. It will be 
necessary to determine a set of engine modes that will generate the 
required combinations of temperature, exhaust flow, oil consumption, and 
NOX to meet the target aging requirements. The development of 
these modes will be an iterative process using the engine and 
independent temperature control features of the aging stand. This 
process assumes that you have already implemented the oil consumption 
increase modifications, and that these have already been stabilized and 
validated to reach the necessary levels of bulk oil exposure. In 
general, we recommend the use of higher engine speeds and loads to 
generate the desired oil consumption, leveraging the temperature 
controls as needed to lower temperature to the targets. Several 
iterations will likely be needed to reach all targets. Note that during 
transitions you may utilize any combination of conditions necessary to 
help primary component catalysts reach the target temperature and flow 
conditions within no more than 5 minutes. For example, you may use a 
higher exhaust flow rate and lower temperature to rapidly cool the 
aftertreatment system to the next temperature. NOX targets do 
not need to be met during transitions. It is permissible to deviate from 
engine-out NOX emission targets if needed to reach the 
temperature, exhaust flow, and oil consumption targets. We recommend 
that you maintain a NOX level that is at the target level or 
higher, but you may lower NOX by up to 25%, if necessary, on 
some modes. Note that validation of oil consumption requires at least 72 
hours of operation. Tune the parameters for infrequent regeneration 
towards then end of this initial development process (such as 
hydrocarbon injection schedules and temperature ramp rates).
    (ii) Final cycle validation. Once the cycle is tuned, conduct a 
final run using the target aftertreatment system to verify conditions 
and log temperatures for heat load calculation. Using the recorded cycle 
data, calculate Dt for all primary component catalysts to 
ensure that you are matching the desired Dt,cycle targets. If 
you are not within 3% of the target 
Dt,cycle, adjust the cycle accordingly. Calculate 
Dt for any secondary catalyst components to verify that they 
are within 3% of either the target Dt 
or the target aging metric. Note that the accelerated aging methodology 
assumes that the relationship between the temperature of the primary and 
secondary catalyst components will the be same as the field 
observations. If this relationship deviates in the lab by having more or 
less heat transfer through the system, it may be necessary to modify 
that relationship on the aging stand. You may need to take measures such 
as adding or removing insulation or utilize external cooling fans to 
help these parameters match more closely.

[[Page 330]]

    (2) Burner-based platform. (i) Cycle development. The burner-based 
platform will be able to meet the exhaust flow, temperature, 
NOX, and oil consumption targets directly without the need 
for additional cycle development. This process assumes that you have 
already implemented and validated your oil consumption exposure methods 
to reach the necessary levels of bulk oil exposure. In addition, you 
must meet the oxygen and water targets during aging modes within 2% for oxygen and 2% for water. 
Note that during transitions you may utilize any combination of 
conditions necessary to help primary component catalysts reach the 
target temperature and flow conditions within no more than 5 minutes. 
For example, you may use a higher exhaust flow rate and lower 
temperature to rapidly cool the aftertreatment system to the next 
temperature. NOX, oxygen, and water targets do not need to be 
met during transitions.
    (ii) Final cycle validation. Once the cycle is tuned, conduct a 
final run using the target aftertreatment system to verify conditions 
and log temperatures for heat load calculation. Using the recorded cycle 
data, calculate Dt for all primary components catalysts to 
ensure that you are matching the desired Dt,cycle targets. If 
you are not within 3% of the target 
Dt,cycle, adjust the cycle accordingly. Calculate 
Dt for any secondary catalyst components to check that they 
are within 3% of either the target Dt 
or the target aging metric. Note that the accelerated aging methodology 
assumes that the relationship between the temperature of the primary and 
secondary catalyst components will the be same as that observed in the 
field. If this relationship deviates in the lab by having more or less 
heat transfer through the system, it may be necessary to modify that 
relationship on the aging stand. You may need to take measures such as 
adding or removing insulation or utilize external cooling fans to help 
these parameters match more closely.
    (b) Aftertreatment break in. Break in the emission-data engine and 
aftertreatment prior to the initial zero-hour test by running both on an 
engine dynamometer as described in subpart E of this part. Use good 
engineering judgment to develop a representative cycle that represents 
the field data. You may use the same data used for accelerated aging 
cycle development or other data. If your system utilizes infrequent 
regeneration, include at least one complete regeneration event, but we 
recommend that you include at least two such events to stabilize 
emissions performance. Your break in process must include at least 125 
hours of engine operation with the aftertreatment system. You may ask to 
use a longer break in duration based on good engineering judgment, to 
ensure that emission performance is stabilized prior to the zero-hour 
testing.
    (c) Initial emission testing. Prior to the start of accelerated 
aging conduct the initial zero-hour emission test and any required 
engine dynamometer aging following the requirements of the standard 
setting part for your engine. Dynaometer aging hours count toward the 
total aging hours.
    (d) Accelerated aging. Following zero-hour emission testing and any 
engine dynamometer aging, perform accelerated aging using the cycle 
validated in either paragraph (a)(1) or (2) of this section. Repeat the 
cycle the number of times required to reach full useful life equivalent 
aging. Interrupt the aging cycle as needed to conduct any scheduled 
intermediate emission tests, clean the DPF of accumulated ash, and for 
any facility releated reasons. We recommended you interrupt aging at the 
end of a given aging cycle, following the completion of any scheduled 
infrequent regeneration event.
    (e) QA tracking and validation. During aging, track a number of 
aging parameters to ensure that fall within the required limits. Correct 
aging parameters as need to remain within the required control limits.
    (1) Thermal load tracking. For each primary catalyst component, 
generate a target line which describes the relationship between aging 
hours on the cycle and cumulative deactivation, Dt. Generate 
control limit lines that are 3% of the target 
line. You must remain within these control limits over the course of 
aging. Adjust aging parameters as needed to remain within these limits 
for the primary catalyst

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components. For each secondary catalyst component, generate both a 
target Dt line and a line describing the target behavior of 
the aging metric directly. You must remain within either 10% of either the Dt line or 3% of the aging metric target line for any secondary 
catalyst component. Adjust aging parameters as needed to remain within 
these limits noting that you must remain within limits for the primary 
components. Adjusting the secondary catalyst aging may require altering 
heat transfer through the system to make it more representative of the 
field aging.
    (2) Oil consumption tracking. Generate a target oil consumption line 
for both the bulk and volatile pathway which describes the relationship 
between oil exposure and aging hours on the cycle. For the engine-based 
stand the control limits are 10% for total oil 
consumption, noting that the volatile pathway must not exceed 30% of the 
total. For the burner-based stand, the controls limits are 5% for both pathways, which are tracked separately.
    (i) Changing engine oil. For an engine-based platform, periodically 
change engine oil to maintain stable oil consumption rates and maintain 
the health of the aging engine. Interrupt aging as needed to perform oil 
changes. Perform a drain-and-weigh measurement. Following an oil change 
you must run at least 4 hours with the exhaust bypassing the 
aftertreatment system to stabilize the new oil. If you see a sudden 
change in oil consumption it may be necessary to stop aging and either 
change oil or correct an issue with the accelerated oil consumption. If 
the aging engine requires repairs to correct an oil consumption issue in 
the middle of aging, you must re-validate the oil consumption rate for 
72 hours before you continue aging. The engine exhaust should be left 
bypassing the aftertreatment system until the repaired engine has been 
validated.
    (ii) Secondary oil consumption validation. If your aftertreatment 
includes a diesel particulate filter, we recommend that you perform 
secondary validation of oil consumption by using clean (soot free) DPF 
weights to track ash loading and compare this mass of ash to the amount 
predicted using the measured oil consumption mass and the oil ash 
concentration. The mass of ash found by DPF weight should fall within a 
range of (55 to 70)% of the of mass predicted from oil consumption 
measurements. Perform this validation at the end of aging, at any 
intermediate emission test points, and at any point where you need to 
clean the DPF of accumulated ash in according with recommended 
maintenance.
    (iii) Sulfur tracking. Generate a fuel sulfur exposure line 
describing the relationship between aging hours and cumulative target 
sulfur exposure mass. The control limits for sulfur exposure are 3%. Log actual fuel consumption and the measured fuel 
sulfur level of the current batch of fuel (if you are doping fuel to 
accelerate sulfur exposure) for engine stand aging. Use these 
measurements to ensure that sulfur exposure remains within the control 
limits. Adjust sulfur doping levels in the fuel from batch to batch as 
needed to stay within limits. If you use gaseous SO2 for 
sulfur acceleration, monitor the mass flow rate of the gaseous sulfur. 
Use these measurements to calculate total sulfur mass exposure, and 
correct SO2 gas flow rates as needed to stay within the 
control limits.
    (f) Emission testing at intermediate and final test points. Conduct 
emission testing at the end of aging and at any intermediate emission 
test points as described in the standard setting part. Following 
installation of the aged aftertreatment system on the emission-data 
engine at intermediate or final test points, prior to the start of 
emission testing, use good engineering judgment to operate the engine 
and aftertreatment system for a number of hours to stabilize emission 
controls and to allow any adaptive controls to update. Declare the 
number of stabilization hours prior to the start of the accelerated 
aging program.



PART 1066_VEHICLE-TESTING PROCEDURES--Table of Contents



             Subpart A_Applicability and General Provisions

Sec.
1066.1 Applicability.
1066.2 Submitting information to EPA under this part.

[[Page 332]]

1066.5 Overview of this part 1066 and its relationship to the standard-
          setting part.
1066.10 Other procedures.
1066.11 xxx
1066.15 Overview of test procedures.
1066.20 Units of measure and overview of calculations.
1066.25 Recordkeeping.

 Subpart B_Equipment, Measurement Instruments, Fuel, and Analytical Gas 
                             Specifications

1066.101 Overview.
1066.105 Ambient controls and vehicle cooling fans.
1066.110 Equipment specifications for emission sampling systems.
1066.120 Measurement instruments.
1066.125 Data updating, recording, and control.
1066.130 Measurement instrument calibrations and verifications.
1066.135 Linearity verification.
1066.140 Diluted exhaust flow calibration.
1066.145 Test fuel, engine fluids, analytical gases, and other 
          calibration standards.
1066.150 Analyzer interference and quench verification limit.

                  Subpart C_Dynamometer Specifications

1066.201 Dynamometer overview.
1066.210 Dynamometers.
1066.215 Summary of verification procedures for chassis dynamometers.
1066.220 Linearity verification for chassis dynamometer systems.
1066.225 Roll runout and diameter verification procedure.
1066.230 Time verification procedure.
1066.235 Speed verification procedure.
1066.240 Torque transducer verification.
1066.245 Response time verification.
1066.250 Base inertia verification.
1066.255 Parasitic loss verification.
1066.260 Parasitic friction compensation evaluation.
1066.265 Acceleration and deceleration verification.
1066.270 Unloaded coastdown verification.
1066.275 Daily dynamometer readiness verification.
1066.290 Verification of speed accuracy for the driver's aid.

                           Subpart D_Coastdown

1066.301 Overview of road-load determination procedures.
1066.305 Procedures for specifying road-load forces for motor vehicles 
          at or below 14,000 pounds GVWR.
1066.310 Coastdown procedures for vehicles above 14,000 pounds GVWR.
1066.315 Dynamometer road-load setting.

    Subpart E_Preparing Vehicles and Running an Exhaust Emission Test

1066.401 Overview.
1066.405 Vehicle preparation, preconditioning, and maintenance.
1066.410 Dynamometer test procedure.
1066.415 Vehicle operation.
1066.420 Test preparation.
1066.425 Performing emission tests.

        Subpart F_Electric Vehicles and Hybrid Electric Vehicles

1066.501 Overview.

                         Subpart G_Calculations

1066.601 Overview.
1066.605 Mass-based and molar-based exhaust emission calculations.
1066.610 Dilution air background correction.
1066.615 NOX intake-air humidity correction.
1066.625 Flow meter calibration calculations.
1066.630 PDP, SSV, and CFV flow rate calculations.
1066.635 NMOG determination.
1066.695 Data requirements.

               Subpart H_Cold Temperature Test Procedures

1066.701 Applicability and general provisions.
1066.710 Cold temperature testing procedures for measuring CO and NMHC 
          emissions and determining fuel economy.

      Subpart I_Exhaust Emission Test Procedures for Motor Vehicles

1066.801 Applicability and general provisions.
1066.805 Road-load power, test weight, and inertia weight class 
          determination.
1066.810 Vehicle preparation.
1066.815 Exhaust emission test procedures for FTP testing.
1066.816 Vehicle preconditioning for FTP testing.
1066.820 Composite calculations for FTP exhaust emissions.
1066.830 Supplemental Federal Test Procedures; overview.
1066.831 Exhaust emission test procedures for aggressive driving.
1066.835 Exhaust emission test procedure for SC03 emissions.
1066.840 Highway fuel economy test procedure.
1066.845 AC17 air conditioning efficiency test procedure.

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             Subpart J_Evaporative Emission Test Procedures

1066.901 Applicability and general provisions.
Test Equipment and Calculations for Evaporative and Refueling Emissions
1066.910 SHED enclosure specifications.
1066.915 Enclosures; auxiliary systems and equipment.
1066.920 Enclosure calibrations.
1066.925 Enclosure calculations for evaporative and refueling emissions.
1066.930 Equipment for point-source measurement of running losses.
Evaporative and Refueling Emission Test Procedures for Motor Vehicles
1066.950 Fuel temperature profile.
1066.955 Diurnal emission test.
1066.960 Running loss test.
1066.965 Hot soak test.
1066.970 Refueling test for liquid fuels.
1066.971 Vehicle and canister preconditioning for the refueling test.
1066.975 Refueling test for LPG.
1066.980 Fuel dispensing spitback procedure.
1066.985 Fuel storage system leak test procedure.

           Subpart K_Definitions and Other Reference Material

1066.1001 Definitions.
1066.1005 Symbols, abbreviations, acronyms, and units of measure.
1066.1010 Incorporation by reference.

    Authority: 42 U.S.C. 7401-7671q.

    Source: 79 FR 23823, Apr. 28, 2014, unless otherwise noted.



             Subpart A_Applicability and General Provisions



Sec.  1066.1  Applicability.

    (a) This part describes the emission measurement procedures that 
apply to testing we require for the following vehicles:
    (1) Model year 2014 and later heavy-duty highway vehicles we 
regulate under 40 CFR part 1037 that are not subject to chassis testing 
for exhaust emissions under 40 CFR part 86.
    (2) Model year 2022 and later motor vehicles (light-duty and heavy-
duty) that are subject to chassis testing for exhaust emissions under 40 
CFR part 86, other than highway motorcycles. See 40 CFR part 86 for 
provisions describing how to implement this part 1066.
    (b) The procedures of this part may apply to other types of 
vehicles, as described in this part and in the standard-setting part.
    (c) The testing in this part 1066 is designed for measuring exhaust, 
evaporative, and refueling emissions. Procedures for measuring 
evaporative and refueling emissions for motor vehicles are in some cases 
integral with exhaust measurement procedures as described in Sec.  
1066.801. Subpart J of this part describes provisions that are unique to 
evaporative and refueling emission measurements. Other subparts in this 
part are written with a primary focus on measurement of exhaust 
emissions.
    (d) The term ``you'' means anyone performing testing under this part 
other than EPA.
    (1) This part is addressed primarily to manufacturers of vehicles, 
but it applies equally to anyone who does testing under this part for 
such manufacturers.
    (2) This part applies to any manufacturer or supplier of test 
equipment, instruments, supplies, or any other goods or services related 
to the procedures, requirements, recommendations, or options in this 
part.
    (e) Paragraph (a) of this section identifies the parts of the CFR 
that define emission standards and other requirements for particular 
types of vehicles. In this part, we refer to each of these other parts 
generically as the ``standard-setting part.'' For example, 40 CFR part 
1037 is the standard-setting part for heavy-duty highway vehicles and 
parts 86 and 600 are the standard-setting parts for light-duty vehicles. 
For vehicles subject to 40 CFR part 86, subpart S, treat subpart I and 
subpart J of this part as belonging to 40 CFR part 86. This means that 
references to the standard-setting part include subpart I and subpart J 
of this part.
    (f) Unless we specify otherwise, the terms ``procedures'' and ``test 
procedures'' in this part include all aspects of vehicle testing, 
including the equipment specifications, calibrations, calculations, and 
other protocols and procedural specifications needed to measure 
emissions.
    (g) For additional information regarding the test procedures in this 
part, visit our website at www.epa.gov, and in particular https://
www.epa.gov/

[[Page 334]]

vehicle-and- fuel-emissions-testing/vehicle-testing- regulations.

[79 FR 23823, Apr. 28, 2014, as amended at 86 FR 34581, June 29, 2021]



Sec.  1066.2  Submitting information to EPA under this part.

    (a) You are responsible for statements and information in your 
applications for certification, requests for approved procedures, 
selective enforcement audits, laboratory audits, production-line test 
reports, or any other statements you make to us related to this part 
1066. If you provide statements or information to someone for submission 
to EPA, you are responsible for these statements and information as if 
you had submitted them to EPA yourself.
    (b) In the standard-setting part and in 40 CFR 1068.101, we describe 
your obligation to report truthful and complete information and the 
consequences of failing to meet this obligation. See also 18 U.S.C. 1001 
and 42 U.S.C. 7413(c)(2). This obligation applies whether you submit 
this information directly to EPA or through someone else.
    (c) We may void any certificates or approvals associated with a 
submission of information if we find that you intentionally submitted 
false, incomplete, or misleading information. For example, if we find 
that you intentionally submitted incomplete information to mislead EPA 
when requesting approval to use alternate test procedures, we may void 
the certificates for all engine families certified based on emission 
data collected using the alternate procedures. This would also apply if 
you ignore data from incomplete tests or from repeat tests with higher 
emission results.
    (d) We may require an authorized representative of your company to 
approve and sign the submission, and to certify that all the information 
submitted is accurate and complete. This includes everyone who submits 
information, including manufacturers and others.
    (e) See 40 CFR 1068.10 for provisions related to confidential 
information. Note however that under 40 CFR 2.301, emission data are 
generally not eligible for confidential treatment.
    (f) Nothing in this part should be interpreted to limit our ability 
under Clean Air Act section 208 (42 U.S.C. 7542) to verify that vehicles 
conform to the regulations.



Sec.  1066.5  Overview of this part 1066 and its relationship to the standard-setting part.

    (a) This part specifies procedures that can apply generally to 
testing various categories of vehicles. See the standard-setting part 
for directions in applying specific provisions in this part for a 
particular type of vehicle. Before using this part's procedures, read 
the standard-setting part to answer at least the following questions:
    (1) What drive schedules must I use for testing?
    (2) Should I warm up the test vehicle before measuring emissions, or 
do I need to measure cold-start emissions during a warm-up segment of 
the duty cycle?
    (3) Which exhaust constituents do I need to measure? Measure all 
exhaust constituents that are subject to emission standards, any other 
exhaust constituents needed for calculating emission rates, and any 
additional exhaust constituents as specified in the standard-setting 
part. See 40 CFR 1065.5 regarding requests to omit measurement of 
N2O and CH4 for vehicles not subject to an 
N2O or CH4 emission standard.
    (4) Do any unique specifications apply for test fuels?
    (5) What maintenance steps may I take before or between tests on an 
emission-data vehicle?
    (6) Do any unique requirements apply to stabilizing emission levels 
on a new vehicle?
    (7) Do any unique requirements apply to test limits, such as ambient 
temperatures or pressures?
    (8) What requirements apply for evaporative and refueling emissions?
    (9) Are there any emission standards specified at particular 
operating conditions or ambient conditions?
    (10) Do any unique requirements apply for durability testing?
    (b) The testing specifications in the standard-setting part may 
differ from the specifications in this part. In cases where it is not 
possible to comply with both the standard-setting part and this

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part, you must comply with the specifications in the standard-setting 
part. The standard-setting part may also allow you to deviate from the 
procedures of this part for other reasons.
    (c) The following table shows how this part divides testing 
specifications into subparts:

       Table 1 of Sec.   1066.5--Description of Part 1066 Subparts
------------------------------------------------------------------------
                                     Describes these specifications or
           This subpart                          procedures
------------------------------------------------------------------------
Subpart A........................  Applicability and general provisions.
Subpart B........................  Equipment for testing.
Subpart C........................  Dynamometer specifications.
Subpart D........................  Coastdowns for testing.
Subpart E........................  How to prepare your vehicle and run
                                    an emission test.
Subpart F........................  How to test electric vehicles and
                                    hybrid electric vehicles.
Subpart G........................  Test procedure calculations.
Subpart H........................  Cold temperature testing.
Subpart I........................  Exhaust emission test procedures for
                                    motor vehicles.
Subpart J........................  Evaporative and refueling emission
                                    test procedures.
Subpart K........................  Definitions and reference material.
------------------------------------------------------------------------



Sec.  1066.10  Other procedures.

    (a) Your testing. The procedures in this part apply for all testing 
you do to show compliance with emission standards, with certain 
exceptions noted in this section. In some other sections in this part, 
we allow you to use other procedures (such as less precise or less 
accurate procedures) if they do not affect your ability to show that 
your vehicles comply with the applicable emission standards. This 
generally requires emission levels to be far enough below the applicable 
emission standards so that any errors caused by greater imprecision or 
inaccuracy do not affect your ability to state unconditionally that the 
engines meet all applicable emission standards.
    (b) Our testing. These procedures generally apply for testing that 
we do to determine if your vehicles comply with applicable emission 
standards. We may perform other testing as allowed by the Act.
    (c) Exceptions. You may use procedures other than those specified in 
this part as described in 40 CFR 1065.10(c). All the test procedures 
noted as exceptions to the specified procedures are considered 
generically as ``other procedures.'' Note that the terms ``special 
procedures'' and ``alternate procedures'' have specific meanings; 
``special procedures'' are those allowed by 40 CFR 1065.10(c)(2) and 
``alternate procedures'' are those allowed by 40 CFR 1065.10(c)(7). If 
we require you to request approval to use other procedures under this 
paragraph (c), you may not use them until we approve your request.

[79 FR 23823, Apr. 28, 2014, 80 FR 9120, Feb. 19, 2015]



Sec.  1066.15  Overview of test procedures.

    This section outlines the procedures to test vehicles that are 
subject to emission standards.
    (a) The standard-setting part describes the emission standards that 
apply. Evaporative and refueling emissions are generally in the form of 
grams total hydrocarbon equivalent per test. We set exhaust emission 
standards in g/mile (or g/km), for the following constituents:
    (1) Total oxides of nitrogen, NOX.
    (2) Hydrocarbons, HC, which may be expressed in the following ways:
    (i) Total hydrocarbons, THC.
    (ii) Nonmethane hydrocarbons, NMHC, which results from subtracting 
methane, CH4, from THC.
    (iii) Total hydrocarbon-equivalent, THCE, which results from 
adjusting THC mathematically to be equivalent on a carbon-mass basis.
    (iv) Nonmethane hydrocarbon-equivalent, NMHCE, which results from 
adjusting NMHC mathematically to be equivalent on a carbon-mass basis.
    (v) Nonmethane organic gases, NMOG, which are calculated either from 
fully or partially speciated measurement of hydrocarbons including 
oxygenates, or by adjusting measured NMHC values based on fuel oxygenate 
properties.
    (3) Particulate matter, PM.
    (4) Carbon monoxide, CO.
    (5) Carbon dioxide, CO2.
    (6) Methane, CH4.
    (7) Nitrous oxide, N2O.
    (8) Formaldehyde, CH2O.
    (b) Note that some vehicles may not be subject to standards for all 
the exhaust emission constituents identified in paragraph (a) of this 
section. Note also that the standard-setting part may include standards 
for pollutants

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not listed in paragraph (a) of this section.
    (c) The provisions of this part apply for chassis dynamometer 
testing where vehicle speed is controlled to follow a prescribed duty 
cycle while simulating vehicle driving through the dynamometer's road-
load settings. We generally set exhaust emission standards over test 
intervals and/or drive schedules, as follows:
    (1) Vehicle operation. Testing involves measuring emissions and 
miles travelled while operating the vehicle on a chassis dynamometer. 
Refer to the definitions of ``duty cycle'' and ``test interval'' in 
Sec.  1066.1001. Note that a single drive schedule may have multiple 
test intervals and require weighting of results from multiple test 
intervals to calculate a composite distance-based emission value to 
compare to the standard.
    (2) Constituent determination. Determine the total mass of each 
exhaust constituent over a test interval by selecting from the following 
methods:
    (i) Continuous sampling. In continuous sampling, measure the exhaust 
constituent's concentration continuously from raw or dilute exhaust. 
Multiply this concentration by the continuous (raw or dilute) flow rate 
at the emission sampling location to determine the constituent's flow 
rate. Sum the constituent's flow rate continuously over the test 
interval. This sum is the total mass of the emitted constituent.
    (ii) Batch sampling. In batch sampling, continuously extract and 
store a sample of raw or dilute exhaust for later measurement. Extract a 
sample proportional to the raw or dilute exhaust flow rate, as 
applicable. You may extract and store a proportional sample of exhaust 
in an appropriate container, such as a bag, and then measure 
NOX, HC, CO, CO2, CH4, N2O, 
and CH2O concentrations in the container after the test 
interval. You may deposit PM from proportionally extracted exhaust onto 
an appropriate substrate, such as a filter. In this case, divide the PM 
by the amount of filtered exhaust to calculate the PM concentration. 
Multiply batch sampled concentrations by the total (raw or dilute) flow 
from which it was extracted during the test interval. This product is 
the total mass of the emitted constituent.
    (iii) Combined sampling. You may use continuous and batch sampling 
simultaneously during a test interval, as follows:
    (A) You may use continuous sampling for some constituents and batch 
sampling for others.
    (B) You may use continuous and batch sampling for a single 
constituent, with one being a redundant measurement, subject to the 
provisions of 40 CFR 1065.201.
    (d) Refer to subpart G of this part and the standard-setting part 
for calculations to determine g/mile emission rates.
    (e) You must use good engineering judgment for all aspects of 
testing under this part. While this part highlights several specific 
cases where good engineering judgment is especially relevant, the 
requirement to use good engineering judgment is not limited to those 
provisions where we specifically re-state this requirement.



Sec.  1066.20  Units of measure and overview of calculations.

    (a) System of units. The procedures in this part follow both 
conventional English units and the International System of Units (SI), 
as detailed in NIST Special Publication 811, which we incorporate by 
reference in Sec.  1066.1010. Except where specified, equations work 
with either system of units. Where the equations depend on the use of 
specific units, the regulation identifies the appropriate units.
    (b) Units conversion. Use good engineering judgment to convert units 
between measurement systems as needed. For example, if you measure 
vehicle speed as kilometers per hour and we specify a precision 
requirement in terms of miles per hour, convert your measured kilometer 
per hour value to miles per hour before comparing it to our 
specification. The following conventions are used throughout this 
document and should be used to convert units as applicable:
    (1) 1 hp = 33,000 ft [middot] lbf/min = 550 ft [middot] lbf/s = 
0.7457 kW.
    (2) 1 lbf = 32.174 ft [middot] lbm/s\2\ = 4.4482 N.
    (3) 1 inch = 25.4 mm.
    (4) 1 mile = 1609.344 m.

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    (5) For ideal gases, 1 [micro]mol/mol = 1 ppm.
    (6) For ideal gases, 10 mmol/mol = 1%.
    (c) Temperature. We generally designate temperatures in units of 
degrees Celsius ( [deg]C) unless a calculation requires an absolute 
temperature. In that case, we designate temperatures in units of Kelvin 
(K). For conversion purposes throughout this part, 0 [deg]C equals 
273.15 K. Unless specified otherwise, always use absolute temperature 
values for multiplying or dividing by temperature.
    (d) Absolute pressure. Measure absolute pressure directly or 
calculate it as the sum of atmospheric pressure plus a differential 
pressure that is referenced to atmospheric pressure. Always use absolute 
pressure values for multiplying or dividing by pressure.
    (e) Rounding. The rounding provisions of 40 CFR 1065.20 apply for 
calculations in this part. This generally specifies that you round final 
values but not intermediate values. Use good engineering judgment to 
record the appropriate number of significant digits for all 
measurements.
    (f) Interpretation of ranges. Interpret a range as a tolerance 
unless we explicitly identify it as an accuracy, repeatability, 
linearity, or noise specification. See 40 CFR 1065.1001 for the 
definition of tolerance. In this part, we specify two types of ranges:
    (1) Whenever we specify a range by a single value and corresponding 
limit values above and below that value (such as X Y), target the associated control point to that single 
value (X). Examples of this type of range include ``10% of maximum pressure'', or ``(30 10) kPa''. In these examples, you would target the 
maximum pressure or 30 kPa, respectively.
    (2) Whenever we specify a range by the interval between two values, 
you may target any associated control point to any value within that 
range. An example of this type of range is ``(40 to 50) kPa''.
    (g) Scaling of specifications with respect to an applicable 
standard. Because this part 1066 applies to a wide range of vehicles and 
emission standards, some of the specifications in this part are scaled 
with respect to a vehicle's applicable standard or weight. This ensures 
that the specification will be adequate to determine compliance, but not 
overly burdensome by requiring unnecessarily high-precision equipment. 
Many of these specifications are given with respect to a ``flow-weighted 
mean'' that is expected at the standard or during testing. Flow-weighted 
mean is the mean of a quantity after it is weighted proportional to a 
corresponding flow rate. For example, if a gas concentration is measured 
continuously from the raw exhaust of an engine, its flow-weighted mean 
concentration is the sum of the products of each recorded concentration 
times its respective exhaust flow rate, divided by the sum of the 
recorded flow rates. As another example, the bag concentration from a 
CVS system is the same as the flow-weighted mean concentration, because 
the CVS system itself flow-weights the bag concentration.



Sec.  1066.25  Recordkeeping.

    (a) The procedures in this part include various requirements to 
record data or other information. Refer to the standard-setting part and 
Sec.  1066.695 regarding specific recordkeeping requirements.
    (b) You must promptly send us organized, written records in English 
if we ask for them. We may review them at any time.
    (c) We may waive specific reporting or recordkeeping requirements we 
determine to be unnecessary for the purposes of this part and the 
standard-setting part. Note that while we will generally keep the 
records required by this part, we are not obligated to keep records we 
determine to be unnecessary for us to keep. For example, while we 
require you to keep records for invalid tests so we may verify that your 
invalidation was appropriate, it is not necessary for us to keep records 
for our own invalid tests.



 Subpart B_Equipment, Measurement Instruments, Fuel, and Analytical Gas 
                             Specifications



Sec.  1066.101  Overview.

    (a) This subpart addresses equipment related to emission testing, as 
well as test fuels and analytical gases.

[[Page 338]]

    (b) The provisions of 40 CFR part 1065 specify engine-based 
procedures for measuring emissions. Except as specified otherwise in 
this part, the provisions of 40 CFR part 1065 apply for testing required 
by this part as follows:
    (1) The provisions of 40 CFR part 1065, subpart B, describe 
equipment specifications for exhaust dilution and sampling systems; 
these specifications apply for testing under this part as described in 
Sec.  1066.110.
    (2) The provisions of 40 CFR part 1065, subpart C, describe 
specifications for measurement instruments; these specifications apply 
for testing under this part as described in Sec.  1066.120.
    (3) The provisions of 40 CFR part 1065, subpart D, describe 
specifications for measurement instrument calibrations and 
verifications; these specifications apply for testing under this part as 
described in Sec.  1066.130.
    (4) The provisions of 40 CFR part 1065, subpart H, describe 
specifications for fuels, engine fluids, and analytical gases; these 
specifications apply for testing under this part as described in Sec.  
1066.145.
    (5) The provisions of 40 CFR part 1065, subpart I, describe 
specifications for testing with oxygenated fuels; these specifications 
apply for NMOG determination as described in Sec.  1066.635.
    (c) The provisions of this subpart are intended to specify systems 
that can very accurately and precisely measure emissions from motor 
vehicles such as light-duty vehicles. To the extent that this level of 
accuracy or precision is not necessary for testing highway motorcycles 
or nonroad vehicles, we may waive or modify the specifications and 
requirements of this part for testing these other vehicles, consistent 
with good engineering judgment. For example, it may be appropriate to 
allow the use of a hydrokinetic dynamometer that is not able to meet all 
the performance specifications described in this subpart.



Sec.  1066.105  Ambient controls and vehicle cooling fans.

    (a) Ambient conditions. Dynamometer testing under this part 
generally requires that you maintain the test cell within a specified 
range of ambient temperature and humidity. Use good engineering judgment 
to maintain relatively uniform temperatures throughout the test cell 
before testing. You are generally not required to maintain uniform 
temperatures throughout the test cell while the vehicle is running due 
to the heat generated by the vehicle. Measured humidity values must 
represent the conditions to which the vehicle is exposed, which includes 
intake air; other than the intake air, humidity does not affect 
emissions, so humidity need not be uniform throughout the test cell.
    (b) General requirements for cooling fans. Use good engineering 
judgment to select and configure fans to cool the test vehicle in a way 
that meets the specifications of paragraph (c) of this section and 
simulates in-use operation. If you demonstrate that the specified fan 
configuration is impractical for special vehicle designs, such as 
vehicles with rear-mounted engines, or it does not provide adequate 
cooling to properly represent in-use operation, you may ask us to 
approve increasing fan capacity or using additional fans.
    (c) Allowable cooling fans for vehicles at or below 14,000 pounds 
GVWR. Cooling fan specifications for vehicles at or below 14,000 pounds 
GVWR depend on the test cycle. Paragraph (c)(1) of this section 
summarizes the cooling fan specifications for the different test cycles; 
the detailed specifications are described in paragraphs (c)(2) through 
(5) of this section. See Sec.  1066.410 for instruction regarding how to 
use the fans during testing.
    (1) Cooling fan specifications for different test cycles are 
summarized as follows:
    (i) For the FTP test cycle, the allowable cooling fan configurations 
are described in paragraphs (c)(2) and (3) of this section.
    (ii) For the HFET test cycle, the allowable cooling fan 
configurations are described in paragraphs (c)(2) and (3) of this 
section.
    (iii) For the US06 test cycle, the allowable cooling fan 
configurations are described in paragraphs (c)(2) and (4) of this 
section.
    (iv) For the LA-92 test cycle, the allowable cooling fan 
configurations are described in paragraphs (c)(2) and (4) of this 
section.

[[Page 339]]

    (v) For SC03 and AC17 test cycles, the allowable cooling fan 
configuration is described in paragraph (c)(5) of this section.
    (2) You may use a road-speed modulated fan system meeting the 
specifications of this paragraph (c)(2) for anything other than SC03 and 
AC17 testing. Use a road-speed modulated fan that achieves a linear 
speed of cooling air at the blower outlet that is within 3.0 mi/hr (1.3 m/s) of the 
corresponding roll speed when vehicle speeds are between 5 and 30 mi/hr, 
and within 6.5 mi/hr (2.9 m/
s) of the corresponding roll speed at higher vehicle speeds; however you 
may limit the fan's maximum linear speed to 70 mi/hr. We recommend that 
the cooling fan have a minimum opening of 0.2 m\2\ and a minimum width 
of 0.8 m.
    (i) Verify the air flow velocity for fan speeds corresponding to 
vehicle speeds of 20 and 40 mi/hr using an instrument that has an 
accuracy of 2% of the measured air flow speed.
    (ii) For fans with rectangular outlets, divide the fan outlet into 
sections as shown in Figure 1 of this section. As illustrated by the `` 
+ '' in the following figure, measure flow from the center of each 
section; do not measure the flow from the center section.
[GRAPHIC] [TIFF OMITTED] TR28AP14.059

    (iii) For fans with circular outlets, divide the fan outlet into 8 
equal sections as shown in Figure 2 of this section. As illustrated by 
the `` + '' in the following figure, measure flow on the radial 
centerline of each section, at a radius of two-thirds of the fan's total 
radius.

[[Page 340]]

[GRAPHIC] [TIFF OMITTED] TR28AP14.060

    (iv) Verify that the uniformity of the fan's axial flow is constant 
across the discharge area within a tolerance of 4.0 mi/hr of the vehicle's speed at fan speeds 
corresponding to 20 mi/hr, and within 8.0 mi/hr at 
fan speeds corresponding to 40 mi/hr. For example, at a vehicle speed of 
20.2 mi/hr, axial flow at all locations denoted by the ``+'' across the 
discharge nozzle must be between 16.2 and 24.2 mi/hr. When measuring the 
axial air flow velocity, use good engineering judgment to determine the 
distance from the nozzle outlet at each point of the fan outlet grid. 
Use these values to calculate a mean air flow velocity across the 
discharge area at each speed setting. The instrument used to verify the 
air velocity must have an accuracy of 2% of the 
measured air flow velocity.
    (v) Use a multi-axis flow meter or another method to verify that the 
fan's air flow perpendicular to the axial air flow is less than 15% of 
the axial air flow, consistent with good engineering judgment. 
Demonstrate this by comparing the perpendicular air flow velocity to the 
mean air flow velocities determined in paragraph (c)(2)(iv) of this 
section at vehicle speeds of 20 and 40 mi/hr.
    (3) You may use a fixed-speed fan with a maximum capacity up to 2.50 
m\3\/s for FTP and HFET testing.
    (4) You may use a fixed-speed fan with a maximum capacity up to 7.10 
m\3\/s for US06 and LA-92 testing.
    (5) For SC03 and AC17 testing, use a road-speed modulated fan with a 
minimum discharge area that is equal to or exceeds the vehicle's frontal 
inlet area. We recommend using a fan with a discharge area of 1.7 m\2\.
    (i) Air flow volumes must be proportional to vehicle speed. Select a 
fan size that will produce a flow volume of approximately 45 m\3\/s at 
60 mi/hr. If this fan is also the only source of test cell air 
circulation or if fan operational mechanics make the 0 mi/hr air flow 
requirement impractical, air flow of 2 mi/hr or less at 0 mi/hr vehicle 
speed is allowed.
    (ii) Verify the uniformity of the fan's axial flow as described in 
paragraph (c)(2)(iv) of this section, except that you must measure the 
axial air flow velocity 60 cm from the nozzle outlet at each point of 
the discharge area grid.
    (iii) Use a multi-axis flow meter or another method to verify that 
the fan's air flow perpendicular to the axial air flow is less than 10% 
of the axial air flow, consistent with good engineering judgment. 
Demonstrate this by comparing the perpendicular air flow velocity to the 
mean air flow velocities determined in paragraph (c)(2)(iv) of this

[[Page 341]]

section at vehicle speeds of 20 and 40 mi/hr.
    (iv) In addition to the road-speed modulated fan, we may approve the 
use of one or more fixed-speed fans to provide proper cooling to 
represent in-use operation, but only up to a total of 2.50 m\3\/s for 
all additional fans.
    (d) Allowable cooling fans for vehicles above 14,000 pounds GVWR. 
For all testing, use a road-speed modulated fan system that achieves a 
linear speed of cooling air at the blower outlet that is within 3.0 mi/hr (1.3 m/s) of the 
corresponding roll speed when vehicle speeds are between 5 and 30 mi/hr, 
and within 10 mi/hr (4.5 m/
s) of the corresponding roll speed at higher vehicle speeds. For 
vehicles above 19,500 pounds GVWR, we recommend that the cooling fan 
have a minimum opening of 2.75 m\2\, a minimum flow rate of 60 m\3\/s at 
a fan speed of 50 mi/hr, and a minimum speed profile in the free stream 
flow, across the duct that is 15% of the target 
flow rate.

[79 FR 23823, Apr. 28, 2014, as amended at 81 FR 74195, Oct. 25, 2016]



Sec.  1066.110  Equipment specifications for emission sampling systems.

    (a) This section specifies equipment related to emission testing, 
other than measurement instruments. This equipment includes dynamometers 
(described further in subpart C of this part) and various emission-
sampling hardware.
    (b) The following equipment specifications apply for testing under 
this part:
    (1) Connect a vehicle's exhaust system to any dilution stage as 
follows:
    (i) Minimize lengths of laboratory exhaust tubing. You may use a 
total length of laboratory exhaust tubing up to 4 m without needing to 
heat or insulate the tubing. However, you may use a total length of 
laboratory exhaust tubing up to 10 m, or up to 15 m for samples not 
involving PM measurement, if you insulate and/or heat the tubing to 
minimize the temperature difference between the exhaust gas and the 
whole tubing wall over the course of the emission test. The laboratory 
exhaust tubing starts at the end of the vehicle's tailpipe and ends at 
the first sample point or the first dilution point. The laboratory 
exhaust tubing may include flexible sections, but we recommend that you 
limit the amount of flexible tubing to the extent practicable. For 
multiple-tailpipe configurations where the tailpipes combine into a 
single flow path for emission sampling, the start of the laboratory 
exhaust tubing may be taken at the last joint where the exhaust flow 
first becomes a single, combined flow.
    (ii) For vehicles above 14,000 pounds GVWR, you may shorten the 
tailpipe up to the outlet of the last aftertreatment device or silencer, 
whichever is furthest downstream.
    (iii) You may insulate or heat any laboratory exhaust tubing.
    (iv) Use laboratory exhaust tubing materials that are smooth-walled 
and not chemically reactive with exhaust constituents. (For purposes of 
this paragraph (b)(1), nominally smooth spiral-style and accordion-style 
flexible tubing are considered to be smooth-walled.) For measurements 
involving PM, tubing materials must also be electrically conductive. 
Stainless steel is an acceptable material for any testing. You may use 
short sections of nonconductive flexible tubing to connect a PM sampling 
system to the vehicle's tailpipe; use good engineering judgment to limit 
the amount of nonconductive surface area exposed to the vehicle's 
exhaust.
    (v) We recommend that you use laboratory exhaust tubing that has 
either a wall thickness of less than 2 mm or is air gap-insulated to 
minimize temperature differences between the wall and the exhaust.
    (vi) You must seal your system to the extent necessary to ensure 
that any remaining leaks do not affect your ability to demonstrate 
compliance with the applicable standards in this chapter. We recommend 
that you seal all known leaks.
    (vii) Electrically ground the entire exhaust system, with the 
exception of nonconductive flexible tubing, as allowed under paragraph 
(b)(1)(iv) of this section.
    (viii) For vehicles with multiple tailpipes, route the exhaust into 
a single flow. To ensure mixing of the multiple

[[Page 342]]

exhaust streams before emission sampling, we recommend a minimum 
Reynolds number, Re#, of 4000 for the combined exhaust 
stream, where Re# is based on the inside diameter of the 
combined flow at the first sampling point. You may configure the exhaust 
system with turbulence generators, such as orifice plates or fins, to 
achieve good mixing; this may be necessary for good mixing if 
Re# is less than 4000. Re# is defined in 40 CFR 
1065.640.
    (2) Use equipment specifications in 40 CFR 1065.140 through 40 CFR 
1065.190, except as follows:
    (i) For PM background measurement, the following provisions apply in 
addition to the provisions in 40 CFR 1065.140(b):
    (A) You need not measure PM background for every test. You may apply 
PM background correction for a single site or multiple sites using a 
moving-average background value as long as your background PM sample 
media (e.g., filters) were all made by the same manufacturer from the 
same material. Use good engineering judgment to determine how many 
background samples make up the moving average and how frequently to 
update those values. For example, you might take one background sample 
per week and average that sample into previous background values, 
maintaining five observations for each calculated average value. 
Background sampling time should be representative of the duration of the 
test interval to which the background correction is applied.
    (B) You may sample background PM from the dilution tunnel at any 
time before or after an emission test using the same sampling system 
used during the emission test. For this background sampling, the 
dilution tunnel blower must be turned on, the vehicle must be 
disconnected from the laboratory exhaust tubing, and the laboratory 
exhaust tubing must be capped. You may run this PM blank test in 
combination with the dilute exhaust flow verification (propane check) in 
40 CFR 1065.341, as long as the exhaust tubing inlet to the CVS has a 
filter meeting the requirements of 40 CFR 1065.140(b)(3).
    (C) The duration of your background sample may be different than 
that of the test cycle in which you are applying the background 
correction, consistent with good engineering judgment.
    (D) Your PM background correction may not exceed 5 [micro]g or 5% of 
the net PM mass expected at the standard, whichever is greater.
    (ii) The provisions of 40 CFR 1065.140(d)(2)(iv) do not apply.
    (iii) For PM samples, configure dilution systems using the following 
limits:
    (A) Control the dilution air temperature as described in 40 CFR 
1065.140(e)(1), except that the temperature may be set to (15 to 52) 
[deg]C. Use good engineering judgment to control PM sample temperature 
as required under 40 CFR 1065.140(e)(4).
    (B) Apply the provisions of this paragraph (b)(2)(iii)(B) instead of 
40 CFR 1065.140(e)(2). Add dilution air to the raw exhaust such that the 
overall dilution factor of diluted exhaust to raw exhaust, as shown in 
Eq. 1066.610-2 or 1066.610-3, is within the range of (7:1 to 20:1). 
Compliance with this dilution factor range may be determined for an 
individual test interval or as a time-weighted average over the entire 
duty cycle as determined in Eq. 1066.610-4. The maximum dilution factor 
limit of 20:1 does not apply for hybrid electric vehicles (HEVs), since 
the dilution factor is infinite when the engine is off; however we 
strongly recommend that you stay under the specified maximum dilution 
factor limit when the engine is running. For partial-flow sampling 
systems, determine dilution factor using Eq. 1066.610-3. To determine 
the overall dilution factor for PM samples utilizing secondary dilution 
air, multiply the dilution factor from the CVS by the dilution ratio of 
secondary dilution air to primary diluted exhaust.
    (C) You may use a higher target filter face velocity as specified in 
40 CFR 1065.170(c)(1)(vi), up to 140 cm/s, if you need to increase 
filter loading for PM measurement.
    (iv) In addition to the allowances in 40 CFR 1065.140(c)(6), you may 
heat the dilution air as described in paragraph (b)(2)(iii)(A) of this 
section to prevent or limit aqueous condensation.
    (v) If you choose to dilute the exhaust by using a remote mix tee, 
which

[[Page 343]]

dilutes the exhaust at the tailpipe, you may use the following 
provisions consistent with good engineering judgment, as long as they do 
not affect your ability to demonstrate compliance with the applicable 
standards in this chapter:
    (A) You may use smooth-walled flexible tubing (including accordion-
style) in the dilution tunnel upstream of locations for flow measurement 
or gaseous emission measurement.
    (B) You may use smooth-walled electrically conductive flexible 
tubing in the dilution tunnel upstream of the location for PM emission 
measurements.
    (C) All inside surfaces upstream of emission sampling must be made 
of 300 series stainless steel or polymer-based materials.
    (D) Use good engineering judgment to ensure that the materials you 
choose do not cause significant loss of PM from your sample.
    (vi) Paragraph (b)(1)(vi) of this section applies instead of 40 CFR 
1065.145(b).
    (vii) Vehicles other than HEVs that apply technology involving 
engine shutdown during idle may apply the sampling provisions of Sec.  
1066.501(c).
    (c) The following table summarizes the requirements of paragraph 
(b)(2) of this section:

 Table 1 of Sec.   1066.110--Summary of Equipment Specifications From 40
        CFR Part 1065, Subpart B, That Apply for Chassis Testing
------------------------------------------------------------------------
                                       Applicability for chassis testing
     40 CFR part 1065 references                under this part
------------------------------------------------------------------------
40 CFR 1065.140.....................  Use all except as noted:
                                      40 CFR 1065.140(b) applies as
                                       described in this section.
                                      Use 40 CFR 1065.140(c)(6), with
                                       the additional allowance
                                       described in this section.
                                      Do not use 40 CFR
                                       1065.140(d)(2)(iv).
                                      Use 40 CFR 1065.140(e)(1) as
                                       described in this section.
                                      Do not use 40 CFR 1065.140(e)(2).
40 CFR 1065.145.....................  Use all except 40 CFR 1065.145(b).
40 CFR 1065.150.....................  Use all.
40 CFR 1065.170.....................  Use all except as noted:
                                      Use 40 CFR 1065.170(c)(1)(vi) as
                                       described in this section.
40 CFR 1065.190.....................  Use all.
------------------------------------------------------------------------


[79 FR 23823, Apr. 28, 2014, as amended at 81 FR 74196, Oct. 25, 2016; 
88 FR 4708, Jan. 24, 2023]



Sec.  1066.120  Measurement instruments.

    The measurement instrument requirements in 40 CFR part 1065, subpart 
C, apply with the following exceptions:
    (a) The provisions of Sec.  1066.125 apply instead of 40 CFR 
1065.202.
    (b) The provisions of 40 CFR 1065.210 and 1065.295 do not apply.



Sec.  1066.125  Data updating, recording, and control.

    This section specifies criteria that your test system must meet for 
updating and recording data. It also specifies criteria for controlling 
the systems related to driver demand, the dynamometer, sampling 
equipment, and measurement instruments.
    (a) Read and record values and calculate mean values relative to a 
specified frequency as follows:
    (1) This paragraph (a)(1) applies where we specify a minimum command 
and control frequency that is greater than the minimum recording 
frequency, such as for sample flow rates from a CVS that does not have a 
heat exchanger. For these measurements, the rate at which you read and 
interpret the signal must be at least as frequent as the minimum command 
and control frequency. You may record values at the same frequency, or 
you may record them as mean values, as long as the frequency of the mean 
values meets the minimum recording frequency. You must use all read 
values, either by recording them or using them to calculate mean values. 
For example, if your system reads and controls the sample flow rate at 
10 Hz, you may record these values at 10 Hz, record them at 5 Hz by 
averaging pairs of consecutive points together, or record them at 1 Hz 
by averaging ten consecutive points together.
    (2) For all other measured values covered by this section, you may 
record the values instantaneously or as mean values, consistent with 
good engineering judgment.
    (3) You may not use rolling averages of measured values where a 
given measured value is included in more than one recorded mean value.
    (b) Use data acquisition and control systems that can command, 
control, and record at the following minimum frequencies:

[[Page 344]]



                   Table 1 of Sec.   1066.125--Data Recording and Control Minimum Frequencies
----------------------------------------------------------------------------------------------------------------
                                                                      Minimum command and
        Applicable section                  Measured values            control frequency     Minimum recording
                                                                              \a\             frequency \b c\
----------------------------------------------------------------------------------------------------------------
Sec.   1066.310...................  Vehicle speed..................  ....................  10 Hz.
Sec.   1066.315...................
Sec.   1066.425...................  Continuous concentrations of     ....................  1 Hz.
                                     raw or dilute analyzers.
Sec.   1066.425...................  Power analyzer.................  ....................  1 Hz.
Sec.   1066.501...................
Sec.   1066.425...................  Bag concentrations of raw or     ....................  1 mean value per test
                                     dilute analyzers.                                      interval.
40 CFR 1065.545...................  Diluted exhaust flow rate from   ....................  1 Hz.
Sec.   1066.425...................   a CVS with a heat exchanger
                                     upstream of the flow
                                     measurement.
40 CFR 1065.545...................  Diluted exhaust flow rate from   5 Hz................  1 Hz means.
Sec.   1066.425...................   a CVS without a heat exchanger
                                     upstream of the flow
                                     measurement.
40 CFR 1065.545...................  Dilution air flow if actively    5 Hz................  1 Hz means.
Sec.   1066.425...................   controlled (for example, a
                                     partial-flow PM sampling
                                     system) \d\.
40 CFR 1065.545...................  Sample flow from a CVS that has  1 Hz................  1 Hz.
Sec.   1066.425...................   a heat exchanger.
40 CFR 1065.545...................  Sample flow from a CVS that      5 Hz................  1 Hz means.
Sec.   1066.425...................   does not have a heat exchanger.
Sec.   1066.420...................  Ambient temperature............  ....................  1 Hz.\e\
Sec.   1066.420...................  Ambient humidity...............  ....................  1 Hz.\e\
Sec.   1066.420...................  Heated sample system             ....................  1 Hz.
                                     temperatures, including PM
                                     filter face.
----------------------------------------------------------------------------------------------------------------
\a\ CFVs that are not using active control are exempt from meeting this requirement due to their operating
  principle.
\b\ 1 Hz means are data reported from the instrument at a higher frequency, but recorded as a series of 1 s mean
  values at a rate of 1 Hz.
\c\ For CFVs in a CVS, the minimum recording frequency is 1 Hz. For CFVs used to control sampling from a CFV
  CVS, the minimum recording frequency is not applicable.
\d\ This is not applicable to CVS dilution air.
\e\ Unless specified elsewhere in this part or the standard-setting part. Note that this provision does not
  apply to soak periods where recording frequencies are not specified. For these instances, we recommend a
  recording frequency of =0.016 Hz.


[79 FR 23823, Apr. 28, 2014, as amended at 80 FR 9120, Feb. 19, 2015]



Sec.  1066.130  Measurement instrument calibrations and verifications.

    The measurement instrument calibration and verification requirements 
in 40 CFR part 1065, subpart D, apply with the following exceptions:
    (a) The calibration and verification provisions of 40 CFR 1065.303 
do not apply for engine speed, torque, fuel rate, or intake air flow.
    (b) The linearity verification provisions of 40 CFR 1065.307 do not 
apply for engine speed, torque, fuel rate, or intake air flow. Section 
1066.135 specifies additional linearity verification provisions that 
apply specifically for chassis testing.
    (c) The provisions of Sec.  1066.220 apply instead 40 CFR 1065.310.
    (d) The provisions of 40 CFR 1065.320, 1065.325, and 1065.395 do not 
apply.
    (e) If you are measuring flow volumetrically (rather than measuring 
based on molar values), the provisions of Sec.  1066.140 apply instead 
of 40 CFR 1065.340.
    (f) The provisions of Sec.  1066.150 apply instead 40 CFR 
1065.350(c), 1065.355(c), 1065.370(c), and 1065.375(c).
    (g) Table 1 of this section summarizes the required and recommended 
calibrations and verifications that are unique to testing under this 
part and indicates when these must be performed. Perform other required 
or recommended calibrations and verifications as described in 40 CFR 
1065.303, with the exceptions noted in this section. Table 1 follows:

    Table 1 of Sec.   1066.130--Summary of Required Calibrations and
                              Verifications
------------------------------------------------------------------------
      Type of calibration or
           verification                     Minimum frequency \a\
------------------------------------------------------------------------
40 CFR 1065.307: Linearity          The linearity verifications from 40
 verification.                       CFR part 1065 do not apply under
                                     this part for engine speed, torque,
                                     fuel rate, or intake air flow; the
                                     linearity verification described in
                                     Sec.   1066.135 applies for the
                                     following measurements:
                                    Dynamometer speed: See Sec.
                                     1066.220.
                                    Dynamometer torque: See Sec.
                                     1066.220.

[[Page 345]]

 
40 CFR 1065.310: Torque...........  This calibration does not apply for
                                     testing under this part; see Sec.
                                     1066.220.
40 CFR 1065.320: Fuel flow........  This calibration does not apply for
                                     testing under this part.
40 CFR 1065.325: Intake flow......  This calibration does not apply for
                                     testing under this part.
40 CFR 1065.340: CVS calibration..  This calibration does not apply for
                                     CVS flow meters calibrated
                                     volumetrically as described in Sec.
                                       1066.140.
40 CFR 1065.345: Vacuum leak......  Required upon initial installation
                                     of the sampling system; recommended
                                     within 35 days before the start of
                                     an emissions test and after
                                     maintenance such as pre-filter
                                     changes.
40 CFR 1065.350(c), 1065.355(c),    These provisions do not apply for
 1065.370(c), and 1065.375(c).       testing under this part; see Sec.
                                     1066.150.
40 CFR 1065.395: Inertial PM        These verifications do not apply for
 balance and weighing.               testing under this part.
------------------------------------------------------------------------
\a\ Perform calibrations and verifications more frequently if needed to
  conform to the measurement system manufacturer's instructions and good
  engineering judgment.



Sec.  1066.135  Linearity verification.

    This section describes requirements for linearity verification that 
are unique to testing under this part. (Note: See the definition of 
``linearity'' in 40 CFR 1065.1001, where we explain that linearity means 
the degree to which measured values agree with respective reference 
values and that the term ``linearity'' is not used to refer to the shape 
of a measurement instrument's unprocessed response curve.) Perform other 
required or recommended calibrations and verifications as described in 
40 CFR 1065.307, with the exceptions noted in this section.
    (a) For gas analyzer linearity, use one of the following options:
    (1) Use instrument manufacturer recommendations and good engineering 
judgment to select at least ten reference values, yrefi, that 
cover the range of values that you expect during testing (to prevent 
extrapolation beyond the verified range during emission testing). We 
recommend selecting zero as one of your reference values. For each range 
calibrated, if the deviation from a least-squares best-fit straight line 
is 2% or less of the value at each data point, concentration values may 
be calculated by use of a straight-line curve fit for that range. If the 
deviation exceeds 2% at any point, use the best-fit nonlinear equation 
that represents the data to within 2% of each test point to determine 
concentration. If you use a gas divider to blend calibration gases, you 
may verify that the calibration curve produced names a calibration gas 
within 2% of its certified concentration. Perform this verification 
between 10 and 60% of the full-scale analyzer range.
    (2) Use the linearity requirements of 40 CFR 1065.307, except for 
CO2 measurements used for determining fuel economy and GHG 
emissions for motor vehicles at or below 14,000 pounds GVWR. If you 
choose this linearity option, you must use the provisions of 40 CFR 
1065.672 to check for drift and make appropriate drift corrections.
    (b) For dilution air, diluted exhaust, and raw exhaust sample flow, 
use a reference flow meter with a blower or pump to simulate flow rates. 
Use a restrictor, diverter valve, variable-speed blower, or variable-
speed pump to control the range of flow rates. Use the reference meter's 
response for the reference values.
    (1) Reference flow meters. Because of the large range in flow 
requirements, we allow a variety of reference meters. For example, for 
diluted exhaust flow for a full-flow dilution system, we recommend a 
reference subsonic venturi flow meter with a restrictor valve and a 
blower to simulate flow rates. For dilution air, diluted exhaust for 
partial-flow dilution, and raw exhaust, we allow reference meters such 
as critical flow orifices, critical flow venturis, laminar flow 
elements, master mass flow standards, or Roots meters. Make sure the 
reference meter is calibrated and its calibration is NIST-traceable. If 
you use the difference of two flow measurements to determine a net flow 
rate, you may use one of the measurements as a reference for the other.

[[Page 346]]

    (2) Reference flow values. Because the reference flow is not 
absolutely constant, sample and record values of Qrefi for 30 
seconds and use the arithmetic mean of the values, Qiref, as 
the reference value. Refer to 40 CFR 1065.602 for an example of 
calculating an arithmetic mean.
    (3) Linearity criteria. The values measured during linearity 
verification for flow meters must meet the following criteria: [verbar] 
xmin(a1-1) + a0 [verbar] <= 1% [middot] 
Qmax; a1 = 0.98-1.02; SEE = <= 2% [middot] 
Qmax; and r\2\ =0.990.
    (c) Perform linearity verifications for the following temperature 
measurements instead of those specified at 40 CFR 1065.307(e)(7):
    (1) Test cell ambient air.
    (2) Dilution air for PM sampling, including CVS, double-dilution, 
and partial-flow systems.
    (3) PM sample.
    (4) Chiller sample, for gaseous sampling systems that use thermal 
chillers to dry samples, and that use chiller temperature to calculate 
dewpoint at the chiller outlet. For testing, if you choose to use the 
high alarm temperature setpoint for the chiller temperature as a 
constant value in determining the amount of water removed from the 
emission sample, you may verify the accuracy of the high alarm 
temperature setpoint using good engineering judgment without following 
the linearity verification for chiller temperature. We recommend that 
you input a simulated reference temperature signal below the alarm 
setpoint, increase this signal until the high alarm trips, and verify 
that the alarm setpoint value is no less than 2 [deg]C below the 
reference value at the trip point.
    (5) CVS flow meter inlet temperature.
    (d) Perform linearity verifications for the following pressure 
measurements instead of those specified at 40 CFR 1065.307(e)(8):
    (1) Raw exhaust static pressure control.
    (2) Barometric pressure.
    (3) CVS flow meter inlet pressure.
    (4) Sample dryer, for gaseous sampling systems that use either 
osmotic-membrane dryers or thermal chillers to dry samples. For your 
testing, if you choose to use a low alarm pressure setpoint for the 
sample dryer pressure as a constant value in determining the amount of 
water removed from the emission sample, you may verify the accuracy of 
the low alarm pressure setpoint using good engineering judgment without 
following the linearity verification for sample dryer pressure. We 
recommend that you input a reference pressure signal above the alarm 
setpoint, decrease this signal until the low alarm trips, and verify 
that the alarm setpoint value is no more than 4 kPa above the reference 
value at the trip point.
    (e) When following procedures or practices that we incorporate by 
reference in Sec.  1066.1010, you must meet the linearity requirements 
given by the procedure or practice for any analytical instruments not 
covered under 40 CFR 1065.307, such as GC-FID or HPLC.

[79 FR 23823, Apr. 28, 2014, as amended at 81 FR 74197, Oct. 25, 2016; 
86 FR 34581, June 29, 2021]



Sec.  1066.140  Diluted exhaust flow calibration.

    (a) Overview. This section describes how to calibrate flow meters 
for diluted exhaust constant-volume sampling (CVS) systems. We recommend 
that you also use this section to calibrate flow meters that use a 
subsonic venturi or ultrasonic flow to measure raw exhaust flow. You may 
follow the molar flow calibration procedures in 40 CFR 1065.340 instead 
of the procedures in this section.
    (b) Scope and frequency. Perform this calibration while the flow 
meter is installed in its permanent position, except as allowed in 
paragraph (c) of this section. Perform this calibration after you change 
any part of the flow configuration upstream or downstream of the flow 
meter that may affect the flow-meter calibration. Perform this 
calibration upon initial CVS installation and whenever corrective action 
does not resolve a failure to meet the diluted exhaust flow verification 
(i.e., propane check) in 40 CFR 1065.341.
    (c) Ex-situ CFV and SSV calibration. You may remove a CFV or SSV 
from its permanent position for calibration as long as the flow meter 
meets the requirements in 40 CFR 1065.340(c).

[[Page 347]]

    (d) Reference flow meter. Calibrate each CVS flow meter using a 
reference flow meter such as a subsonic venturi flow meter, a long-
radius ASME/NIST flow nozzle, a smooth approach orifice, a laminar flow 
element, or an ultrasonic flow meter. Use a reference flow meter that 
reports quantities that are NIST-traceable within 1% uncertainty. Use this reference flow meter's response 
to flow as the reference value for CVS flow-meter calibration.
    (e) Configuration. Calibrate the system with any upstream screens or 
other restrictions that will be used during testing and that could 
affect the flow ahead of the flow meter. You may not use any upstream 
screen or other restriction that could affect the flow ahead of the 
reference flow meter, unless the flow meter has been calibrated with 
such a restriction.
    (f) PDP calibration. Calibrate each positive-displacement pump (PDP) 
to determine a flow-versus-PDP speed equation that accounts for flow 
leakage across sealing surfaces in the PDP as a function of PDP inlet 
pressure. Determine unique equation coefficients for each speed at which 
you operate the PDP. Calibrate a PDP flow meter as follows:
    (1) Connect the system as shown in Figure 1 of this section.
    (2) Leaks between the calibration flow meter and the PDP must be 
less than 0.3% of the total flow at the lowest calibrated flow point; 
for example, at the highest restriction and lowest PDP-speed point.
    (3) While the PDP operates, maintain a constant temperature at the 
PDP inlet within 2% of the mean absolute inlet 
temperature, Tin.
    (4) Set the PDP speed to the first speed point at which you intend 
to calibrate.
    (5) Set the variable restrictor to its wide-open position.
    (6) Operate the PDP for at least 3 min to stabilize the system. 
Continue operating the PDP and record the mean values of at least 30 
seconds of sampled data of each of the following quantities:
    (i) The mean flow rate of the reference flow meter, 
Viref. This may include several measurements of different 
quantities, such as reference meter pressures and temperatures, for 
calculating Viref.
    (ii) The mean temperature at the PDP inlet, Tin.
    (iii) The mean static absolute pressure at the PDP inlet, 
Pin.
    (iv) The mean static absolute pressure at the PDP outlet, 
Pout.
    (v) The mean PDP speed, fnPDP.
    (7) Incrementally close the restrictor valve to decrease the 
absolute pressure at the inlet to the PDP, Pin.
    (8) Repeat the steps in paragraphs (f)(6) and (7) of this section to 
record data at a minimum of six restrictor positions ranging from the 
wide-open restrictor position to the minimum expected pressure at the 
PDP inlet or the maximum expected differential (outlet minus inlet) 
pressure across the PDP during testing.
    (9) Calibrate the PDP by using the collected data and the equations 
in Sec.  1066.625(a).
    (10) Repeat the steps in paragraphs (f)(6) through (9) of this 
section for each speed at which you operate the PDP.
    (11) Use the equations in Sec.  1066.630(a) to determine the PDP 
flow equation for emission testing.
    (12) Verify the calibration by performing a CVS verification (i.e., 
propane check) as described in 40 CFR 1065.341.
    (13) During emission testing ensure that the PDP is not operated 
either below the lowest inlet pressure point or above the highest 
differential pressure point in the calibration data.
    (g) SSV calibration. Calibrate each subsonic venturi (SSV) to 
determine its discharge coefficient, Cd, for the expected 
range of inlet pressures. Calibrate an SSV flow meter as follows:
    (1) Configure your calibration system as shown in Figure 1 of this 
section.
    (2) Verify that any leaks between the calibration flow meter and the 
SSV are less than 0.3% of the total flow at the highest restriction.
    (3) Start the blower downstream of the SSV.
    (4) While the SSV operates, maintain a constant temperature at the 
SSV inlet within 2% of the mean absolute inlet 
temperature, Tin.
    (5) Set the variable restrictor or variable-speed blower to a flow 
rate greater

[[Page 348]]

than the greatest flow rate expected during testing. You may not 
extrapolate flow rates beyond calibrated values, so we recommend that 
you make sure the Reynolds number, Re#, at the SSV throat at 
the greatest calibrated flow rate is greater than the maximum 
Re# expected during testing.
    (6) Operate the SSV for at least 3 min to stabilize the system. 
Continue operating the SSV and record the mean of at least 30 seconds of 
sampled data of each of the following quantities:
    (i) The mean flow rate of the reference flow meter, 
Viref. This may include several measurements of different 
quantities for calculating Viref, such as reference meter 
pressures and temperatures.
    (ii) The mean temperature at the venturi inlet, Tin.
    (iii) The mean static absolute pressure at the venturi inlet, 
pin.
    (iv) Mean static differential pressure between the static pressure 
at the venturi inlet and the static pressure at the venturi throat, 
[Delta]pssv.
    (7) Incrementally close the restrictor valve or decrease the blower 
speed to decrease the flow rate.
    (8) Repeat the steps in paragraphs (g)(6) and (7) of this section to 
record data at a minimum of ten flow rates.
    (9) Determine an equation to quantify Cd as a function of 
Re# by using the collected data and the equations in Sec.  
1066.625(b). Section 1066.625 also includes statistical criteria for 
validating the Cd versus Re# equation.
    (10) Verify the calibration by performing a CVS verification (i.e., 
propane check) as described in 40 CFR 1065.341 using the new 
Cd versus Re# equation.
    (11) Use the SSV only between the minimum and maximum calibrated 
Re#. If you want to use the SSV at a lower or higher 
Re#, you must recalibrate the SSV.
    (12) Use the equations in Sec.  1066.630(b) to determine SSV flow 
during a test.
    (h) CFV calibration. The calibration procedure described in this 
paragraph (h) establishes the value of the calibration coefficient, 
Kv, at measured values of pressure, temperature and air flow. 
Calibrate the CFV up to the highest expected pressure ratio, r, 
according to Sec.  1066.625. Calibrate the CFV as follows:
    (1) Configure your calibration system as shown in Figure 1 of this 
section.
    (2) Verify that any leaks between the calibration flow meter and the 
CFV are less than 0.3% of the total flow at the highest restriction.
    (3) Start the blower downstream of the CFV.
    (4) While the CFV operates, maintain a constant temperature at the 
CFV inlet within 2% of the mean absolute inlet 
temperature, Tin.
    (5) Set the variable restrictor to its wide-open position. Instead 
of a variable restrictor, you may alternately vary the pressure 
downstream of the CFV by varying blower speed or by introducing a 
controlled leak. Note that some blowers have limitations on nonloaded 
conditions.
    (6) Operate the CFV for at least 3 min to stabilize the system. 
Continue operating the CFV and record the mean values of at least 30 
seconds of sampled data of each of the following quantities:
    (i) The mean flow rate of the reference flow meter, 
Viref. This may include several measurements of different 
quantities, such as reference meter pressures and temperatures, for 
calculating Viref.
    (ii) The mean temperature at the venturi inlet, Tin.
    (iii) The mean static absolute pressure at the venturi inlet, 
pin.
    (iv) The mean static differential pressure between the CFV inlet and 
the CFV outlet, [Delta]pCFV.
    (7) Incrementally close the restrictor valve or decrease the 
downstream pressure to decrease the differential pressure across the 
CFV, [Delta]pCFV.
    (8) Repeat the steps in paragraphs (h)(6) and (7) of this section to 
record mean data at a minimum of ten restrictor positions, such that you 
test the fullest practical range of [Delta]pCFV expected 
during testing. We do not require that you remove calibration components 
or CVS components to calibrate at the lowest possible restriction.
    (9) Determine Kv and the highest allowable pressure 
ratio, r, according to Sec.  1066.625.
    (10) Use Kv to determine CFV flow during an emission 
test. Do not use the CFV above the highest allowed r, as determined in 
Sec.  1066.625.

[[Page 349]]

    (11) Verify the calibration by performing a CVS verification (i.e., 
propane check) as described in 40 CFR 1065.341.
    (12) If your CVS is configured to operate multiple CFVs in parallel, 
calibrate your CVS using one of the following methods:
    (i) Calibrate every combination of CFVs according to this section 
and Sec.  1066.625(c). Refer to Sec.  1066.630(c) for instructions on 
calculating flow rates for this option.
    (ii) Calibrate each CFV according to this section and Sec.  
1066.625. Refer to Sec.  1066.630 for instructions on calculating flow 
rates for this option.
    (i) Ultrasonic flow meter calibration. [Reserved]

[[Page 350]]

[GRAPHIC] [TIFF OMITTED] TR25OC16.234


[[Page 351]]



[79 FR 23823, Apr. 28, 2014, as amended at 81 FR 74197, Oct. 25, 2016]



Sec.  1066.145  Test fuel, engine fluids, analytical gases,
and other calibration standards.

    (a) Test fuel. Use test fuel as specified in the standard-setting 
part, or as specified in 40 CFR part 1065, subpart H, if it is not 
specified in the standard-setting part.
    (b) Lubricating oil. Use lubricating oil as specified in 40 CFR 
1065.740. For two-stroke engines that involve a specified mixture of 
fuel and lubricating oil, mix the lubricating oil with the fuel 
according to the manufacturer's specifications.
    (c) Coolant. For liquid-cooled engines, use coolant as specified in 
40 CFR 1065.745.
    (d) Analytical gases. Use analytical gases that meet the 
requirements of 40 CFR 1065.750.
    (e) Mass standards. Use mass standards that meet the requirements of 
40 CFR 1065.790.



Sec.  1066.150  Analyzer interference and quench verification limit.

    Analyzers must meet the interference and quench verification limits 
in the following table on the lowest, or most representative, instrument 
range that will be used during emission testing, instead of those 
specified in 40 CFR part 1065, subpart D:

      Table 1 of Sec.   1066.150--Analyzer Interference and Quench
                           Verification Limits
------------------------------------------------------------------------
              Verification                            Limit
------------------------------------------------------------------------
40 CFR 1065.350........................  2% of
                                          full scale.
40 CFR 1065.355........................  2% of
                                          full scale.
40 CFR 1065.370........................  2% of
                                          full scale.
40 CFR 1065.375........................  2% of the
                                          flow-weighted mean
                                          concentration of N2O expected
                                          at the standard.
------------------------------------------------------------------------



                  Subpart C_Dynamometer Specifications



Sec.  1066.201  Dynamometer overview.

    This subpart addresses chassis dynamometers and related equipment.



Sec.  1066.210  Dynamometers.

    (a) General requirements. A chassis dynamometer typically uses 
electrically generated load forces combined with its rotational inertia 
to recreate the mechanical inertia and frictional forces that a vehicle 
exerts on road surfaces (known as ``road load''). Load forces are 
calculated using vehicle-specific coefficients and response 
characteristics. The load forces are applied to the vehicle tires by 
rolls connected to motor/absorbers. The dynamometer uses a load cell to 
measure the forces the dynamometer rolls apply to the vehicle's tires.
    (b) Accuracy and precision. The dynamometer's output values for road 
load must be NIST-traceable. We may determine traceability to a specific 
national or international standards organization to be sufficient to 
demonstrate NIST-traceability. The force-measurement system must be 
capable of indicating force readings as follows:
    (1) For dynamometer testing of vehicles at or below 20,000 pounds 
GVWR, the dynamometer force-measurement system must be capable of 
indicating force readings during a test to a resolution of 0.05% of the maximum load-cell force simulated by the 
dynamometer or 9.8 N (2.2 
lbf), whichever is greater.
    (2) For dynamometer testing of vehicles above 20,000 pounds GVWR, 
the force-measurement system must be capable of indicating force 
readings during a test to a resolution of 0.05% of 
the maximum load-cell force simulated by the dynamometer or 39.2 N (8.8 lbf), whichever is 
greater.
    (c) Test cycles. The dynamometer must be capable of fully simulating 
vehicle performance over applicable test cycles for the vehicles being 
tested as referenced in the corresponding standard-setting part, 
including operation at the combination of inertial and road-load forces 
corresponding to maximum road-load conditions and maximum simulated 
inertia at the highest acceleration rate experienced during testing.
    (d) Component requirements. The following specifications apply:
    (1) The nominal roll diameter must be 120 cm or greater. The 
dynamometer must have an independent drive roll for each drive axle as 
tested under Sec.  1066.410(g), except that two drive axles may share a 
single drive roll. Use good engineering judgment to ensure that

[[Page 352]]

the dynamometer roll diameter is large enough to provide sufficient 
tire-roll contact area to avoid tire overheating and power losses from 
tire-roll slippage.
    (2) Measure and record force and speed at 10 Hz or faster. You may 
convert measured values to 1-Hz, 2-Hz, or 5-Hz values before your 
calculations, using good engineering judgment.
    (3) The load applied by the dynamometer simulates forces acting on 
the vehicle during normal driving according to the following equation:
[GRAPHIC] [TIFF OMITTED] TR29JN21.264

Where:

FR = total road-load force to be applied at the surface of the roll. The 
          total force is the sum of the individual tractive forces 
          applied at each roll surface.
i = a counter to indicate a point in time over the driving schedule. For 
          a dynamometer operating at 10-Hz intervals over a 600-second 
          driving schedule, the maximum value of i should be 6,000.
A = a vehicle-specific constant value representing the vehicle's 
          frictional load in lbf or newtons. See subpart D of this part.
Gi = instantaneous road grade, in percent. If your duty cycle 
          is not subject to road grade, set this value to 0.
B = a vehicle-specific coefficient representing load from drag and 
          rolling resistance, which are a function of vehicle speed, in 
          lbf/(mi/hr) or N[middot]s/m. See subpart D of this part.
v = instantaneous linear speed at the roll surfaces as measured by the 
          dynamometer, in mi/hr or m/s. Let vi-1 = 0 for i = 
          0.
C = a vehicle-specific coefficient representing aerodynamic effects, 
          which are a function of vehicle speed squared, in lbf/(mi/
          hr)\2\ or N[middot]s\2\/m\2\. See subpart D of this part.
Me = the vehicle's effective mass in lbm or kg, including the 
          effect of rotating axles as specified in Sec.  1066.310(b)(7).
t = elapsed time in the driving schedule as measured by the dynamometer, 
          in seconds. Let ti-1 = 0 for i = 0.
M = the measured vehicle mass, in lbm or kg.
ag = acceleration of Earth's gravity = 9.80665 m/s\2\.

    (4) We recommend that a dynamometer capable of testing vehicles at 
or below 20,000 pounds GVWR be designed to apply an actual road-load 
force within 1% or 9.8 N 
(2.2 lbf) of the reference value, whichever is 
greater. Note that slightly higher errors may be expected during highly 
transient operation for vehicles above 8,500 pounds GVWR.
    (e) Dynamometer manufacturer instructions. This part specifies that 
you follow the dynamometer manufacturer's recommended procedures for 
things such as calibrations and general operation. If you perform 
testing with a dynamometer that you manufactured or if you otherwise do 
not have these recommended procedures, use good engineering judgment to 
establish the additional procedures and specifications we specify in 
this part, unless we specify otherwise. Keep records to describe these 
recommended procedures and how they are consistent with good engineering 
judgment, including any quantified error estimates.

[79 FR 23823, Apr. 28, 2014, as amended at 81 FR 74198, Oct. 25, 2016; 
86 FR 34581, June 29, 2021]



Sec.  1066.215  Summary of verification procedures for chassis dynamometers.

    (a) Overview. This section describes the overall process for 
verifying and calibrating the performance of chassis dynamometers.
    (b) Scope and frequency. The following table summarizes the required 
and recommended calibrations and verifications described in this subpart 
and indicates when they must occur:

[[Page 353]]



       Table 1 of Sec.   1066.215--Summary of Required Dynamometer
                              Verifications
------------------------------------------------------------------------
     Type of verification                Minimum frequency \a\
------------------------------------------------------------------------
Sec.   1066.220: Linearity     Speed: Upon initial installation, within
 verification.                  370 days before testing, and after major
                                maintenance. Torque (load): Upon initial
                                installation and after major
                                maintenance.
Sec.   1066.225: Roll runout   Upon initial installation and after major
 and diameter verification.     maintenance.
Sec.   1066.230: Time          Upon initial installation and after major
 verification.                  maintenance.
Sec.   1066.235: Speed         Upon initial installation, within 370
 measurement verification.      days before testing, and after major
                                maintenance.
Sec.   1066.240: Torque        Upon initial installation, within 7 days
 (load) transducer              of testing, and after major maintenance.
 verification.
Sec.   1066.245: Response      Upon initial installation, within 370
 time verification.             days before testing, and after major
                                maintenance.
Sec.   1066.250: Base inertia  Upon initial installation and after major
 verification.                  maintenance.
Sec.   1066.255: Parasitic     Upon initial installation, after major
 loss verification.             maintenance, and upon failure of a
                                verification in Sec.   1066.270 or Sec.
                                 1066.275.
Sec.   1066.260: Parasitic     Upon initial installation, after major
 friction compensation          maintenance, and upon failure of a
 verification.                  verification in Sec.   1066.270 or Sec.
                                 1066.275.
Sec.   1066.265: Acceleration  Upon initial installation and after major
 and deceleration               maintenance.
 verification.
Sec.   1066.270: Unloaded      Upon initial installation, within 7 days
 coastdown verification.        of testing, and after major maintenance.
Sec.   1066.275 Dynamometer    Upon initial installation, within 1 day
 readiness verification.        before testing, and after major
                                maintenance.
------------------------------------------------------------------------
\a\ Perform calibrations and verifications more frequently, according to
  measurement system manufacturer instructions and good engineering
  judgment.

    (c) Automated dynamometer verifications and calibrations. In some 
cases, dynamometers are designed with internal diagnostic and control 
features to accomplish the verifications and calibrations specified in 
this subpart. You may use these automated functions instead of following 
the procedures we specify in this subpart to demonstrate compliance with 
applicable requirements, consistent with good engineering judgment.
    (d) Sequence of verifications and calibrations. Upon initial 
installation and after major maintenance, perform the verifications and 
calibrations in the same sequence as noted in Table 1 of this section, 
except that you may perform speed linearity verification after the 
verifications in Sec. Sec.  1066.225 and 1066.230. At other times, you 
may need to perform specific verifications or calibrations in a certain 
sequence, as noted in this subpart. If you perform major maintenance on 
a specific component, you are required to perform verifications and 
calibrations only on components or parameters that are affected by the 
maintenance.
    (e) Corrections. Unless the regulation directs otherwise, if the 
dynamometer fails to meet any specified calibration or verification, 
make any necessary adjustments or repairs such that the dynamometer 
meets the specification before running a test. Repairs required to meet 
specifications are generally considered major maintenance under this 
part.



Sec.  1066.220  Linearity verification for chassis dynamometer systems.

    (a) Scope and frequency. Perform linearity verification for 
dynamometer speed and torque at least as frequently as indicated in 
Table 1 of Sec.  1066.215. The intent of linearity verification is to 
determine that the system responds accurately and proportionally over 
the measurement range of interest. Linearity verification generally 
consists of introducing a series of at least 10 reference values to a 
measurement system. The measurement system quantifies each reference 
value. The measured values are then collectively compared to the 
reference values by using a least-squares linear regression and the 
linearity criteria specified in Table 1 of this section.
    (b) Performance requirements. If a measurement system does not meet 
the applicable linearity criteria in Table 1 of this section, correct 
the deficiency by re-calibrating, servicing, or replacing components as 
needed. Repeat the linearity verification after correcting

[[Page 354]]

the deficiency to ensure that the measurement system meets the linearity 
criteria. Before you may use a measurement system that does not meet 
linearity criteria, you must demonstrate to us that the deficiency does 
not adversely affect your ability to demonstrate compliance with the 
applicable standards in this chapter.
    (c) Procedure. Use the following linearity verification protocol, or 
use good engineering judgment to develop a different protocol that 
satisfies the intent of this section, as described in paragraph (a) of 
this section:
    (1) In this paragraph (c), the letter ``y'' denotes a generic 
measured quantity, the superscript over-bar denotes an arithmetic mean 
(such as y), and the subscript ``ref'' denotes the known or 
reference quantity being measured.
    (2) Operate the dynamometer system at the specified operating 
conditions. This may include any specified adjustment or periodic 
calibration of the dynamometer system.
    (3) Set dynamometer speed and torque to zero.
    (4) Verify the dynamometer speed or torque signal based on the 
dynamometer manufacturer's recommendations.
    (5) After verification, check for zero speed and torque. Use good 
engineering judgment to determine whether or not to rezero or re-verify 
speed and torque before continuing.
    (6) For both speed and torque, use the dynamometer manufacturer's 
recommendations and good engineering judgment to select reference 
values, yrefi, that cover a range of values that you expect 
would prevent extrapolation beyond these values during emission testing. 
We recommend selecting zero speed and zero torque as reference values 
for the linearity verification.
    (7) Use the dynamometer manufacturer's recommendations and good 
engineering judgment to select the order in which you will introduce the 
series of reference values. For example, you may select the reference 
values randomly to avoid correlation with previous measurements and to 
avoid the influence of hysteresis; you may select reference values in 
ascending or descending order to avoid long settling times of reference 
signals; or you may select values to ascend and then descend to 
incorporate the effects of any instrument hysteresis into the linearity 
verification.
    (8) Set the dynamometer to operate at a reference condition.
    (9) Allow time for the dynamometer to stabilize while it measures 
the reference values.
    (10) At a recording frequency of at least 1 Hz, measure speed and 
torque values for 30 seconds and record the arithmetic mean of the 
recorded values,. Refer to 40 CFR 1065.602 for an example of calculating 
an arithmetic mean.
    (11) Repeat the steps in paragraphs (c)(8) though (10) of this 
section until you measure speeds and torques at each of the reference 
settings.
    (12) Use the arithmetic means, yi, and reference values, 
yrefi, to calculate least-squares linear regression 
parameters and statistical values to compare to the minimum performance 
criteria specified in Table 1 of this section. Use the calculations 
described in 40 CFR 1065.602. Using good engineering judgment, you may 
weight the results of individual data pairs (i.e., 
(yrefi,yi)), in the linear regression 
calculations. Table 1 follows:

        Table 1 of Sec.   1066.220--Dynamometer Measurement Systems that Require Linearity Verifications
----------------------------------------------------------------------------------------------------------------
                                                                       Linearity criteria
                                              ------------------------------------------------------------------
      Measurement system          Quantity        [bond]ymin
                                                [middot] (a1-1)        a1              SEE             r \2\
                                                  + a0 [bond]
----------------------------------------------------------------------------------------------------------------
Speed........................  n               <=0.05% [middot]       0.98-1.02  <=2% [middot]    =0.
                                                nmax.                             nmax.                      990
Torque (load)................  T               <=1% [middot]          0.99-1.01  <=1% [middot]    =0.
                                                Tmax.                             Tmax.                      990
----------------------------------------------------------------------------------------------------------------

    (d) Reference signals. Generate reference values for the linearity-
verification protocol in paragraph (c)

[[Page 355]]

of this section as described for speed and torque in 40 CFR 1065.307(d).

[79 FR 23823, Apr. 28, 2014, as amended at 88 FR 4708, Jan. 24, 2023]



Sec.  1066.225  Roll runout and diameter verification procedure.

    (a) Overview. This section describes the verification procedure for 
roll runout and roll diameter. Roll runout is a measure of the variation 
in roll radius around the circumference of the roll.
    (b) Scope and frequency. Perform these verifications upon initial 
installation and after major maintenance that could affect roll surface 
finish or dimensions (such as resurfacing or polishing).
    (c) Roll runout procedure. Verify roll runout based on the following 
procedure, or an equivalent procedure based on good engineering 
judgment:
    (1) Perform this verification with laboratory and dynamometer 
temperatures stable and at equilibrium. Release the roll brake and shut 
off power to the dynamometer. Remove any dirt, rubber, rust, and debris 
from the roll surface. Mark measurement locations on the roll surface 
using a marker. Mark the roll at a minimum of four equally spaced 
locations across the roll width; we recommend taking measurements every 
150 mm across the roll. Secure the marker to the deck plate adjacent to 
the roll surface and slowly rotate the roll to mark a clear line around 
the roll circumference. Repeat this process for all measurement 
locations.
    (2) Measure roll runout using an indicator with a probe that allows 
for measuring the position of the roll surface relative to the roll 
centerline as it turns through a complete revolution. The indicator must 
have some means of being securely mounted adjacent to the roll. The 
indicator must have sufficient range to measure roll runout at all 
points, with a minimum accuracy of 0.025 mm. 
Calibrate the indicator according to the instrument manufacturer's 
instructions.
    (3) Position the indicator adjacent to the roll surface at the 
desired measurement location. Position the shaft of the indicator 
perpendicular to the roll such that the point of the indicator is 
slightly touching the surface of the roll and can move freely through a 
full rotation of the roll. Zero the indicator according to the 
instrument manufacturer's instructions. Avoid distortion of the runout 
measurement from the weight of a person standing on or near the mounted 
dial indicator.
    (4) Slowly turn the roll through a complete rotation and record the 
maximum and minimum values from the indicator. Calculate runout as the 
difference between these maximum and minimum values.
    (5) Repeat the steps in paragraphs (c)(3) and (4) of this section 
for all measurement locations.
    (6) The roll runout must be less than 0.254 mm (0.0100 inches) at 
all measurement locations.
    (d) Diameter procedure. Verify roll diameter based on the following 
procedure, or an equivalent procedure based on good engineering 
judgment:
    (1) Prepare the laboratory and the dynamometer as specified in 
paragraph (c)(1) of this section.
    (2) Measure roll diameter using a Pi Tape[supreg]. Orient the Pi 
Tape[supreg] to the marker line at the desired measurement location with 
the Pi Tape[supreg] hook pointed outward. Temporarily secure the Pi 
Tape[supreg] to the roll near the hook end with adhesive tape. Slowly 
turn the roll, wrapping the Pi Tape[supreg] around the roll surface. 
Ensure that the Pi Tape[supreg] is flat and adjacent to the marker line 
around the full circumference of the roll. Attach a 2.26-kg weight to 
the hook of the Pi Tape[supreg] and position the roll so that the weight 
dangles freely. Remove the adhesive tape without disturbing the 
orientation or alignment of the Pi Tape[supreg].
    (3) Overlap the gage member and the vernier scale ends of the Pi 
Tape[supreg] to read the diameter measurement to the nearest 0.01 mm. 
Follow the manufacturer's recommendation to correct the measurement to 
20 [deg]C, if applicable.
    (4) Repeat the steps in paragraphs (d)(2) and (3) of this section 
for all measurement locations.
    (5) The measured roll diameter must be within 0.254 mm of the specified nominal value at all 
measurement locations. You may revise the nominal value to meet this 
specification, as long as you use the corrected nominal

[[Page 356]]

value for all calculations in this subpart.



Sec.  1066.230  Time verification procedure.

    (a) Overview. This section describes how to verify the accuracy of 
the dynamometer's timing device.
    (b) Scope and frequency. Perform this verification upon initial 
installation and after major maintenance.
    (c) Procedure. Perform this verification using one of the following 
procedures:
    (1) WWV method. You may use the time and frequency signal broadcast 
by NIST from radio station WWV as the time standard if the trigger for 
the dynamometer timing circuit has a frequency decoder circuit, as 
follows:
    (i) Contact station WWV by telephone by dialing (303) 499-7111 and 
listen for the time announcement. Verify that the trigger started the 
dynamometer timer. Use good engineering judgment to minimize error in 
receiving the time and frequency signal.
    (ii) After at least 1000 seconds, re-dial station WWV and listen for 
the time announcement. Verify that the trigger stopped the dynamometer 
timer.
    (iii) Compare the measured elapsed time, yact, to the 
corresponding time standard, yref, to determine the time 
error, yerror, using the following equation:
[GRAPHIC] [TIFF OMITTED] TR28AP14.063

    (2) Ramping method. You may use an operator-defined ramp function to 
serve as the time standard as follows:
    (i) Set up a signal generator to output a marker voltage at the peak 
of each ramp to trigger the dynamometer timing circuit. Output the 
designated marker voltage to start the verification period.
    (ii) After at least 1000 seconds, output the designated marker 
voltage to end the verification period.
    (iii) Compare the measured elapsed time between marker signals, 
yact, to the corresponding time standard, yref, to 
determine the time error, yerror, using Eq. 1066.230-1.
    (3) Dynamometer coastdown method. You may use a signal generator to 
output a known speed ramp signal to the dynamometer controller to serve 
as the time standard as follows:
    (i) Generate upper and lower speed values to trigger the start and 
stop functions of the coastdown timer circuit. Use the signal generator 
to start the verification period.
    (ii) After at least 1000 seconds, use the signal generator to end 
the verification period.
    (iii) Compare the measured elapsed time between trigger signals, 
yact, to the corresponding time standard, yref, to 
determine the time error, yerror, using Eq. 1066.230-1.
    (d) Performance evaluation. The time error determined in paragraph 
(c) of this section may not exceed 0.001%.



Sec.  1066.235  Speed verification procedure.

    (a) Overview. This section describes how to verify the accuracy of 
the dynamometer speed determination. When performing this verification, 
you must also ensure the dynamometer speed at any devices used to 
display or record vehicle speed (such as a driver's aid) is 
representative of the speed input from the dynamometer speed 
determination.
    (b) Scope and frequency. Perform this verification upon initial 
installation, within 370 days before testing, and after major 
maintenance.
    (c) Procedure. Use one of the following procedures to verify the 
accuracy and resolution of the dynamometer speed simulation:
    (1) Pulse method. Connect a universal frequency counter to the 
output of the

[[Page 357]]

dynamometer's speed-sensing device in parallel with the signal to the 
dynamometer controller. The universal frequency counter must be 
calibrated according to the counter manufacturer's instructions and be 
capable of measuring with enough accuracy to perform the procedure as 
specified in this paragraph (c)(1). Make sure the instrumentation does 
not affect the signal to the dynamometer control circuits. Determine the 
speed error as follows:
    (i) Set the dynamometer to speed-control mode. Set the dynamometer 
speed to a value of approximately 4.5 m/s (10 mi/hr); record the output 
of the frequency counter after 10 seconds. Determine the roll speed, 
vact, using the following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.236

Where:

f = frequency of the dynamometer speed sensing device, accurate to at 
          least four significant figures.
droll = nominal roll diameter, accurate to the nearest 1.0 
          mm, consistent with Sec.  1066.225(d).
n = the number of pulses per revolution from the dynamometer roll speed 
          sensor.

    Example: 

f = 2.9231 Hz = 2.9231 s-1
droll = 904.40 mm = 0.90440 m
[GRAPHIC] [TIFF OMITTED] TR25OC16.237

vact = 8.3053 m/s

    (ii) Repeat the steps in paragraph (c)(1)(i) of this section for the 
maximum speed expected during testing and at least two additional evenly 
spaced speed points between the starting speed and the maximum speed 
point.
    (iii) Compare the calculated roll speed, vact, to each 
corresponding speed set point, vref, to determine values for 
speed error at each set point, verror, using the following 
equation:
[GRAPHIC] [TIFF OMITTED] TR28AP14.147

    Example: 
vact = 8.3053 m/s
vref = 8.3000 m/s
verror = 8.3053 - 8.3000 = 0.0053 m/s

    (2) Frequency method. Install a piece of tape in the shape of an 
arrowhead on the surface of the dynamometer roll near the outer edge. 
Put a reference mark on the deck plate in line with the tape. Install a 
stroboscope or photo tachometer on the deck plate and direct the flash 
toward the tape on the roll. The stroboscope or photo tachometer must be 
calibrated according to the instrument manufacturer's instructions and 
be capable of measuring with enough accuracy to perform the procedure as 
specified in this paragraph

[[Page 358]]

(c)(2). Determine the speed error as follows:
    (i) Set the dynamometer to speed-control mode. Set the dynamometer 
speed to a speed value of approximately 4.5 m/s (10 mi/hr). Tune the 
stroboscope or photo tachometer until the signal matches the dynamometer 
roll speed. Record the frequency. Determine the roll speed, 
yact, using Eq. 1066.235-1, using the stroboscope or photo 
tachometer's frequency for f.
    (ii) Repeat the steps in paragraph (c)(2)(i) of this section for the 
maximum speed expected during testing and at least two additional evenly 
spaced speed points between the starting speed and the maximum speed 
point.
    (iii) Compare the calculated roll speed, vact, to each 
corresponding speed set point, vref, to determine values for 
speed error at each set point, yerror, using Eq. 1066.235-2.
    (d) Performance evaluation. The speed error determined in paragraph 
(c) of this section may not exceed 0.02 m/s at any 
speed set point.

[79 FR 23823, Apr. 28, 2014, as amended at 80 FR 9120, Feb. 19, 2015; 81 
FR 74199, Oct. 25, 2016]



Sec.  1066.240  Torque transducer verification.

    Verify torque-measurement systems by performing the verifications 
described in Sec. Sec.  1066.270 and 1066.275.



Sec.  1066.245  Response time verification.

    (a) Overview. This section describes how to verify the dynamometer's 
response time to a step change in tractive force.
    (b) Scope and frequency. Perform this verification upon initial 
installation, within 370 days before testing (i.e., annually), and after 
major maintenance.
    (c) Procedure. Use the dynamometer's automated process to verify 
response time. You may perform this test either at two different inertia 
settings corresponding approximately to the minimum and maximum vehicle 
weights you expect to test or using base inertia and two acceleration 
rates that cover the range of acceleration rates experienced during 
testing (such as 0.5 and 8 (mi/hr)/s). Use good engineering judgment to 
select road-load coefficients representing vehicles of the appropriate 
weight. Determine the dynamometer's settling response time, 
ts, based on the point at which there are no measured results 
more than 10% above or below the final equilibrium value, as illustrated 
in Figure 1 of this section. The observed settling response time must be 
less than 100 milliseconds for each inertia setting. Figure 1 follows:

[[Page 359]]

[GRAPHIC] [TIFF OMITTED] TR28AP14.066


[79 FR 23823, Apr. 28, 2014, as amended at 81 FR 74199, Oct. 25, 2016]



Sec.  1066.250  Base inertia verification.

    (a) Overview. This section describes how to verify the dynamometer's 
base inertia.
    (b) Scope and frequency. Perform this verification upon initial 
installation and after major maintenance, such as maintenance that could 
affect roll inertia.
    (c) Procedure. Verify the base inertia using the following 
procedure:
    (1) Warm up the dynamometer according to the dynamometer 
manufacturer's instructions. Set the dynamometer's road-load inertia to 
zero, turning off any electrical simulation of road load and inertia so 
that the base inertia of the dynamometer is the only inertia present. 
Motor the rolls to 5 mi/hr. Apply a constant force to accelerate the 
roll at a nominal rate of 1 (mi/hr)/s. Measure the elapsed time to 
accelerate from 10 to 40 mi/hr, noting the corresponding speed and time 
points to the nearest 0.01 mi/hr and 0.01 s. Also determine mean force 
over the measurement interval.
    (2) Starting from a steady roll speed of 45 mi/hr, apply a constant 
force to the roll to decelerate the roll at a nominal rate of 1 mi/hr/s. 
Measure the elapsed time to decelerate from 40 to 10 mi/hr, noting the 
corresponding speed and time points to the nearest 0.01 mi/hr and 0.01 
s. Also determine mean force over the measurement interval.
    (3) Repeat the steps in paragraphs (c)(1) and (2) of this section 
for a total of five sets of results at the nominal acceleration rate and 
the nominal deceleration rate.
    (4) Use good engineering judgment to select two additional 
acceleration and deceleration rate pairs that cover the middle and upper 
rates expected during testing. Repeat the steps in paragraphs (c)(1) 
through (3) of this section at each of these additional acceleration and 
deceleration rates.

[[Page 360]]

    (5) Determine the base inertia, Ib, for each measurement 
interval using the following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.238

Where:

F = mean dynamometer force over the measurement interval as measured by 
          the dynamometer.
vfinal = roll surface speed at the end of the measurement 
          interval to the nearest 0.01 mi/hr.
vinit = roll surface speed at the start of the measurement 
          interval to the nearest 0.01 mi/hr.
[Delta]t = elapsed time during the measurement interval to the nearest 
          0.01 s.

    Example: 
F = 1.500 lbf = 48.26 ft[middot]lbm/s\2\
vfinal = 40.00 mi/hr = 58.67 ft/s
vinit = 10.00 mi/hr = 14.67 ft/s
[Delta]t = 30.00 s
[GRAPHIC] [TIFF OMITTED] TR25OC16.239

Ib = 32.90 lbm
    (6) Calculate the base inertia error, Iberror, for each 
of the thirty measured base inertia values, Ib, by comparing 
it to the manufacturer's stated base inertia, Ibref, using 
the following equation:
[GRAPHIC] [TIFF OMITTED] TR28AP14.069

    Example: 
Ibref = 32.96 lbm
Ibact = 32.90 lbm (from paragraph (c)(5) of this section)

[[Page 361]]

[GRAPHIC] [TIFF OMITTED] TR28AP14.070

    (7) Determine the base inertia mean value ib, from the 
ten acceleration and deceleration interval base inertia values for each 
of the three acceleration/deceleration rates. Then determine the base 
inertia mean value, ib, from the base inertia values 
corresponding to acceleration/deceleration rates. Calculate base inertia 
mean values as described in 40 CFR 1065.602(b)
    (8) Calculate the inertia error for the final base inertia mean 
value from paragraph (c)(7) of this section. Use Eq. 1066.250-2, 
substituting the final base inertia mean value from paragraph (c)(7) of 
this section for the individual base inertia.
    (d) Performance evaluation. The dynamometer must meet the following 
specifications to be used for testing under this part:
    (1) All base inertia errors determined under paragraph (c)(6) of 
this section may not exceed 1.0%.
    (2) The inertia error for the final base inertia mean value 
determined under paragraph (c)(8) of this section may not exceed 0.20%.

[79 FR 23823, Apr. 28, 2014, as amended at 81 FR 74199, Oct. 25, 2016]



Sec.  1066.255  Parasitic loss verification.

    (a) Overview. Verify the dynamometer's parasitic loss as described 
in this section, and correct as necessary. This procedure determines the 
dynamometer's internal losses that it must overcome to simulate road 
load. Characterize these losses in a parasitic loss curve that the 
dynamometer uses to apply compensating forces to maintain the desired 
road-load force at the roll surface.
    (b) Scope and frequency. Perform this verification upon initial 
installation, after major maintenance, and upon failure of a 
verification in either Sec.  1066.270 or Sec.  1066.275.
    (c) Procedure. Perform this verification by following the 
dynamometer manufacturer's specifications to establish a parasitic loss 
curve, taking data at fixed speed intervals to cover the range of 
vehicle speeds that will occur during testing. You may zero the load 
cell at a selected speed if that improves your ability to determine the 
parasitic loss. Parasitic loss forces may never be negative. Note that 
the torque transducers must be mathematically zeroed and spanned prior 
to performing this procedure.
    (d) Performance evaluation. Some dynamometers automatically update 
the parasitic loss curve for further testing. If this is not the case, 
compare the new parasitic loss curve to the original parasitic loss 
curve from the dynamometer manufacturer or the most recent parasitic 
loss curve you programmed into the dynamometer. You may reprogram the 
dynamometer to accept the new curve in all cases, and you must reprogram 
the dynamometer if any point on the new curve departs from the earlier 
curve by more than 9.0 N (2.0 lbf) for dynamometers capable of testing vehicles at 
or below 20,000 pounds GVWR, or 36.0 N (8.0 lbf) for dynamometers not capable of testing 
vehicles at or below 20,000 pounds GVWR.

[79 FR 23823, Apr. 28, 2014, as amended at 80 FR 9120, Feb. 19, 2015; 86 
FR 34581, June 29, 2021]



Sec.  1066.260  Parasitic friction compensation evaluation.

    (a) Overview. This section describes how to verify the accuracy of 
the dynamometer's friction compensation.
    (b) Scope and frequency. Perform this verification upon initial 
installation, after major maintenance, and upon failure of a 
verification in either Sec.  1066.270 or Sec.  1066.275. Note that this 
procedure relies on proper verification of speed and torque, as 
described in Sec. Sec.  1066.235 and 1066.240. You must also

[[Page 362]]

first verify the dynamometer's parasitic loss curve as specified in 
Sec.  1066.255.
    (c) Procedure. Use the following procedure to verify the accuracy of 
the dynamometer's friction compensation:
    (1) Warm up the dynamometer as specified by the dynamometer 
manufacturer.
    (2) Perform a torque verification as specified by the dynamometer 
manufacturer. For torque verifications relying on shunt procedures, if 
the results do not conform to specifications, recalibrate the 
dynamometer using NIST-traceable standards as appropriate until the 
dynamometer passes the torque verification. Do not change the 
dynamometer's base inertia to pass the torque verification.
    (3) Set the dynamometer inertia to the base inertia with the road-
load coefficients A, B, and C set to 0. Set the dynamometer to speed-
control mode with a target speed of 50 mi/hr or a higher speed 
recommended by the dynamometer manufacturer. Once the speed stabilizes 
at the target speed, switch the dynamometer from speed-control to 
torque-control and allow the roll to coast for 60 seconds. Record the 
initial and final speeds and the corresponding start and stop times. If 
friction compensation is executed perfectly, there will be no change in 
speed during the measurement interval.
    (4) Calculate the power equivalent of friction compensation error, 
FCerror, using the following equation:
[GRAPHIC] [TIFF OMITTED] TR29JN21.265

Where:

I = dynamometer inertia setting.
t = duration of the measurement interval, accurate to at least 0.01 s.
vinit = the roll speed corresponding to the start of the 
          measurement interval, accurate to at least 0.05 mi/hr.
vfinal = the roll speed corresponding to the end of the 
          measurement interval, accurate to at least 0.05 mi/hr.
    Example: 
I = 2000 lbm = 62.16 lbf[middot]s\2\/ft
t = 60.0 s
vinit = 9.2 mi/hr = 13.5 ft/s
vfinal = 10.0 mi/hr = 14.7 ft/s
[GRAPHIC] [TIFF OMITTED] TR29JN21.266

FCerror = -17.5 ft[middot]lbf/s =-0.032 hp
    (5) The friction compensation error may not exceed 0.15 hp for dynamometers capable of testing vehicles at 
or below 20,000 pounds GVWR, or 0.6 hp for 
dynamometers not capable of testing vehicles at or below 20,000 pounds 
GVWR.

[79 FR 23823, Apr. 28, 2014, as amended at 81 FR 74200, Oct. 25, 2016; 
86 FR 34581, June 29, 2021]



Sec.  1066.265  Acceleration and deceleration verification.

    (a) Overview. This section describes how to verify the dynamometer's 
ability to achieve targeted acceleration and deceleration rates. 
Paragraph (c) of this section describes how this verification applies 
when the dynamometer is programmed directly for a specific acceleration 
or deceleration rate. Paragraph (d) of this section describes how this 
verification applies when the dynamometer is programmed with a 
calculated force to achieve a

[[Page 363]]

targeted acceleration or deceleration rate.
    (b) Scope and frequency. Perform this verification or an equivalent 
procedure upon initial installation and after major maintenance that 
could affect acceleration and deceleration accuracy. Note that this 
procedure relies on proper verification of speed as described in Sec.  
1066.235.
    (c) Verification of acceleration and deceleration rates. Activate 
the dynamometer's function generator for measuring roll revolution 
frequency. If the dynamometer has no such function generator, set up a 
properly calibrated external function generator consistent with the 
verification described in this paragraph (c). Use the function generator 
to determine actual acceleration and deceleration rates as the 
dynamometer traverses speeds between 10 and 40 mi/hr at various nominal 
acceleration and deceleration rates. Verify the dynamometer's 
acceleration and deceleration rates as follows:
    (1) Set up start and stop frequencies specific to your dynamometer 
by identifying the roll-revolution frequency, f, in revolutions per 
second (or Hz) corresponding to 10 mi/hr and 40 mi/hr vehicle speeds, 
accurate to at least four significant figures, using the following 
equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.242

Where:

v = the target roll speed, in inches per second (corresponding to drive 
          speeds of 10 mi/hr or 40 mi/hr).
n = the number of pulses from the dynamometer's roll-speed sensor per 
          roll revolution.
droll = roll diameter, in inches.

    (2) Program the dynamometer to accelerate the roll at a nominal rate 
of 1 mi/hr/s from 10 mi/hr to 40 mi/hr. Measure the elapsed time to 
reach the target speed, to the nearest 0.01 s. Repeat this measurement 
for a total of five runs. Determine the actual acceleration rate for 
each run, aact, using the following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.243

Where:

aact = acceleration rate (decelerations have negative 
          values).
vfinal = the target value for the final roll speed.
vinit = the setpoint value for the initial roll speed.
t = time to accelerate from vinit to vfinal.

    Example: 
vfinal = 40 mi/hr
vinit = 10 mi/hr
t = 30.003 s
[GRAPHIC] [TIFF OMITTED] TR25OC16.244


[[Page 364]]


aact = 0.999 (mi/hr)/s

    (3) Program the dynamometer to decelerate the roll at a nominal rate 
of 1 (mi/hr)/s from 40 mi/hr to 10 mi/hr. Measure the elapsed time to 
reach the target speed, to the nearest 0.01 s. Repeat this measurement 
for a total of five runs. Determine the actual acceleration rate, 
aact, using Eq. 1066.265-2.
    (4) Repeat the steps in paragraphs (c)(2) and (3) of this section 
for additional acceleration and deceleration rates in 1 (mi/hr)/s 
increments up to and including one increment above the maximum 
acceleration rate expected during testing. Average the five repeat runs 
to calculate a mean acceleration rate, aact, at each setting.
    (5) Compare each mean acceleration rate, aact, to the 
corresponding nominal acceleration rate, aref, to determine 
values for acceleration error, aerror, using the following 
equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.245

    Example: 
aact = 0.999 (mi/hr)/s
aref = 1 (mi/hr)/s
[GRAPHIC] [TIFF OMITTED] TR25OC16.246

aerror = -0.100%

    (d) Verification of forces for controlling acceleration and 
deceleration. Program the dynamometer with a calculated force value and 
determine actual acceleration and deceleration rates as the dynamometer 
traverses speeds between 10 and 40 mi/hr at various nominal acceleration 
and deceleration rates. Verify the dynamometer's ability to achieve 
certain acceleration and deceleration rates with a given force as 
follows:
    (1) Calculate the force setting, F, using the following equation:
    [GRAPHIC] [TIFF OMITTED] TR29JN21.267
    
Where:

Ib = the dynamometer manufacturer's stated base inertia, in 
          lbf[middot]s\2\/ft.
a = nominal acceleration rate, in ft/s\2\.
    Example: 
Ib = 2967 lbm = 92.217 lbf[middot]s\2\/ft
a = 1 (mi/hr)/s = 1.4667 ft/s\2\
F = 92.217[middot][verbarlm]1.4667[verbarlm]
F = 135.25 lbf

    (2) Set the dynamometer to road-load mode and program it with a 
calculated force to accelerate the roll at a nominal rate of 1 (mi/hr)/s 
from 10 mi/hr to 40 mi/hr. Measure the elapsed time to reach the target 
speed, to the nearest 0.01 s. Repeat this measurement for a total of 
five runs. Determine the actual

[[Page 365]]

acceleration rate, aact, for each run using Eq. 1066.265-2. 
Repeat this step to determine measured ``negative acceleration'' rates 
using a calculated force to decelerate the roll at a nominal rate of 1 
(mi/hr)/s from 40 mi/hr to 10 mi/hr. Average the five repeat runs to 
calculate a mean acceleration rate, aact, at each setting.
    (3) Repeat the steps in paragraph (d)(2) of this section for 
additional acceleration and deceleration rates as specified in paragraph 
(c)(4) of this section.
    (4) Compare each mean acceleration rate, aact, to the 
corresponding nominal acceleration rate, aref, to determine 
values for acceleration error, aerror, using Eq. 1066.265-3.
    (e) Performance evaluation. The acceleration error from paragraphs 
(c)(5) and (d)(4) of this section may not exceed 1.0%.

[79 FR 23823, Apr. 28, 2014, as amended at 81 FR 74200, Oct. 25, 2016; 
86 FR 34582, June 29, 2021]



Sec.  1066.270  Unloaded coastdown verification.

    (a) Overview. Use force measurements to verify the dynamometer's 
settings based on coastdown procedures.
    (b) Scope and frequency. Perform this verification upon initial 
installation, within 7 days of testing, and after major maintenance.
    (c) Procedure. This procedure verifies the dynamometer's settings 
derived from coastdown testing. For dynamometers that have an automated 
process for this procedure, perform this evaluation by setting the 
initial speed, final speed, inertial coefficients, and road-load 
coefficients as required for each test, using good engineering judgment 
to ensure that these values properly represent in-use operation. Use the 
following procedure if your dynamometer does not perform this 
verification with an automated process:
    (1) Warm up the dynamometer as specified by the dynamometer 
manufacturer.
    (2) With the dynamometer in coastdown mode, set the dynamometer 
inertia for the smallest vehicle weight that you expect to test and set 
A, B, and C road-load coefficients to values typical of those used 
during testing. Program the dynamometer to coast down over the 
dynamometer operational speed range (typically from a speed of 80 mi/hr 
through a minimum speed at or below 10 mi/hr). Perform at least one 
coastdown run over this speed range, collecting data over each 10 mi/hr 
interval.
    (3) Repeat the steps in paragraph (c)(2) of this section with the 
dynamometer inertia and road-load coefficients set for the largest 
vehicle weight that you expect to test.
    (4) Determine the mean coastdown force, F, for each speed and 
inertia setting for each of the coastdowns performed using the following 
equation:
[GRAPHIC] [TIFF OMITTED] TR29JN21.268

Where:

F = the mean force measured during the coastdown for each speed interval 
          and inertia setting, expressed in lbf and rounded to four 
          significant figures.
I = the dynamometer's inertia setting, in lbf[middot]s\2\/ft.
vinit = the speed at the start of the coastdown interval, 
          expressed in ft/s to at least four significant figures.
vfinal = the speed at the end of the coastdown interval, 
          expressed in ft/s to at least four significant figures.
t = coastdown time for each speed interval and inertia setting, accurate 
          to at least 0.01 s.
    Example: 
I = 2000 lbm = 62.16 lbf[middot]s\2\/ft
vinit = 25 mi/hr = 36.66 ft/s
vfinal = 15 mi/hr = 22.0 ft/s

[[Page 366]]

t = 5.00 s
[GRAPHIC] [TIFF OMITTED] TR29JN21.269

F = 182.3 lbf
    (5) Calculate the target value of coastdown force, Fref, 
based on the applicable dynamometer parameters for each speed interval 
and inertia setting.
    (6) Compare the mean value of the coastdown force measured for each 
speed interval and inertia setting, Fact, to the 
corresponding Fref to determine values for coastdown force 
error, Ferror, using the following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.250

    Example: 
Fref = 192 lbf
Fact = 191 lbf
[GRAPHIC] [TIFF OMITTED] TR25OC16.251

Ferror = 0.5%
    (d) Performance evaluation. The coastdown force error determined in 
paragraph (c) of this section may not exceed the following:
    (1) For vehicles at or below 20,000 pounds GVWR, the maximum 
allowable error, Ferrormax, for all speed intervals and 
inertia settings is 1.0% or the value determined from Eq. 1066.270-3, 
whichever is greater.
[GRAPHIC] [TIFF OMITTED] TR25OC16.252

    Example: 
Fref = 192 lbf

[[Page 367]]

[GRAPHIC] [TIFF OMITTED] TR25OC16.253

Ferrormax = 1.14%

    (2) For vehicles above 20,000 pounds GVWR, the maximum allowable 
error, Ferrormax, for all speed intervals and inertia 
settings is 1.0% or the value determined from Eq. 1066.270-3 
(substituting 8.8 lbf for 2.2 lbf in the numerator), whichever is 
greater.
    (e) Remedy for nonconforming dynamometers. If the dynamometer is not 
able to meet this requirement, diagnose and repair the dynamometer 
before continuing with emission testing. Diagnosis should include 
performing the verifications in Sec.  1066.255 and Sec.  1066.260.

[79 FR 23823, Apr. 28, 2014, as amended at 80 FR 9120, Feb. 19, 2015; 81 
FR 74201, Oct. 25, 2016; 86 FR 34582, June 29, 2021]



Sec.  1066.275  Daily dynamometer readiness verification.

    (a) Overview. This section describes how to verify that the 
dynamometer is ready for emission testing.
    (b) Scope and frequency. Perform this verification upon initial 
installation, within 1 day before testing, and after major maintenance. 
You may run this within 7 days before testing if you accumulate data to 
support a less frequent verification interval.
    (c) Procedure. For dynamometers that have an automated process for 
this verification procedure, perform this evaluation by setting the 
initial speed and final speed and the inertial and road-load 
coefficients as required for the test, using good engineering judgment 
to ensure that these values properly represent in-use operation. Use the 
following procedure if your dynamometer does not perform this 
verification with an automated process:
    (1) With the dynamometer in coastdown mode, set the dynamometer 
inertia to the base inertia with the road-load coefficient A set to 20 
lbf (or a force that results in a coastdown time of less than 10 
minutes) and coefficients B and C set to 0. Program the dynamometer to 
coast down for one 10 mi/hr interval from 55 mi/hr down to 45 mi/hr. If 
your dynamometer is not capable of performing one discrete coastdown, 
then coast down with preset 10 mi/hr intervals that include a 55 mi/hr 
to 45 mi/hr interval.
    (2) Perform the coastdown.
    (3) Determine the coastdown force and coastdown force error using 
Eqs. 1066.270-1 and 1066.270-2.
    (d) Performance evaluation. The coastdown force error determined in 
paragraph (c) of this section may not exceed the following:
    (1) For vehicles at or below 20,000 pounds GVWR, 1.0% or the value 
determined from Eq. 1066.270-3, whichever is greater.
    (2) For vehicles above 20,000 pounds GVWR, 1.0% or the value 
determined from Eq. 1066.270-3 (substituting 8.8 lbf for 2.2 lbf), 
whichever is greater.
    (e) Remedy for nonconforming dynamometers. If the verification 
results fail to meet the performance criteria in paragraph (d) of this 
section, perform the procedure up to two additional times. If the 
dynamometer is consistently unable to meet the performance criteria, 
diagnose and repair the dynamometer before continuing with emission 
testing. Diagnosis should include performing the verifications in Sec.  
1066.255 and Sec.  1066.260.

[79 FR 23823, Apr. 28, 2014, as amended at 81 FR 74201, Oct. 25, 2016; 
86 FR 34582, June 29, 2021]



Sec.  1066.290  Verification of speed accuracy for the driver's aid.

    Use good engineering judgment to provide a driver's aid that 
facilitates compliance with the requirements of Sec.  1066.425. Verify 
the speed accuracy of the driver's aid as described in Sec.  1066.235.



                           Subpart D_Coastdown



Sec.  1066.301  Overview of road-load determination procedures.

    Vehicle testing on a chassis dynamometer involves simulating the 
road-load force, which is the sum of forces

[[Page 368]]

acting on a vehicle from aerodynamic drag, tire rolling resistance, 
driveline losses, and other effects of friction. Determine dynamometer 
settings to simulate road-load force in two stages. First, perform a 
road-load force specification by characterizing on-road operation. 
Second, perform a road-load derivation to determine the appropriate 
dynamometer load settings to simulate the road-load force specification 
from the on-road test.
    (a) The procedures described in this subpart are used to determine 
the road-load target coefficients (A, B, and C) for the simulated road-
load equation in Sec.  1066.210(d)(3).
    (b) The general procedure for determining road-load force is 
performing coastdown tests and calculating road-load coefficients. This 
procedure is described in SAE J1263 and SAE J2263 (incorporated by 
reference in Sec.  1066.1010). Continued testing based on the 2008 
version of SAE J2263 is optional, except that it is no longer available 
for testing starting with model year 2026. This subpart specifies 
certain deviations from those procedures for certain applications.
    (c) Use good engineering judgment for all aspects of road-load 
determination. For example, minimize the effects of grade by performing 
coastdown testing on reasonably level surfaces and determining 
coefficients based on average values from vehicle operation in opposite 
directions over the course.

[80 FR 9121, Feb. 19, 2015, as amended at 81 FR 74201, Oct. 25, 2016; 88 
FR 4708, Jan. 24, 2023]



Sec.  1066.305  Procedures for specifying road-load forces for motor 
vehicles at or below 14,000 pounds GVWR.

    (a) For motor vehicles at or below 14,000 pounds GVWR, develop 
representative road-load coefficients to characterize each vehicle 
covered by a certificate of conformity. Calculate road-load coefficients 
by performing coastdown tests using the provisions of SAE J1263 and SAE 
J2263 (incorporated by reference in Sec.  1066.1010). This protocol 
establishes a procedure for determination of vehicle road load force for 
speeds between 115 and 15 km/hr (71.5 and 9.3 mi/hr); the final result 
is a model of road-load force (as a function of speed) during operation 
on a dry, level road under reference conditions of 20 [deg]C, 98.21 kPa, 
no wind, no precipitation, and the transmission in neutral. You may use 
other methods that are equivalent to SAE J2263, such as equivalent test 
procedures or analytical modeling, to characterize road load using good 
engineering judgment. Determine dynamometer settings to simulate the 
road-load profile represented by these road-load target coefficients as 
described in Sec.  1066.315. Supply representative road-load forces for 
each vehicle at speeds above 15 km/hr (9.3 mi/hr), and up to 115 km/hr 
(71.5 mi/hr), or the highest speed from the range of applicable duty 
cycles.
    (b) For cold temperature testing described in subpart H of this 
part, determine road-load target coefficients using one of the following 
methods:
    (1) You may perform coastdown tests or use other methods to 
characterize road load as described in paragraph (a) of this section 
based on vehicle operation at a nominal ambient temperature of -7 [deg]C 
(20 [deg]F).
    (2) You may multiply each of the road-load target coefficients 
determined using the procedures described in paragraph (a) of this 
section by 1.1 to approximate a 10 percent decrease in coastdown time 
for the test vehicle.

[80 FR 9121, Feb. 19, 2015, as amended at 81 FR 74202, Oct. 25, 2016]



Sec.  1066.310  Coastdown procedures for vehicles above 14,000 pounds GVWR.

    This section describes coastdown procedures that are unique to 
vehicles above 14,000 pounds GVWR. These procedures are valid for 
calculating road-load coefficients for chassis and post-transmission 
powerpack testing. These procedures are also valid for calculating drag 
area (CdA) to demonstrate compliance with Phase 1 greenhouse 
gas emission standards under 40 CFR part 1037.
    (a) Determine road-load coefficients by performing a minimum of 16 
valid coastdown runs (8 in each direction).
    (b) Follow the provisions of Sections 1 through 9 of SAE J1263 and 
SAE J2263 (incorporated by reference in Sec.  1066.1010), except as 
described in this paragraph (b). The terms and variables

[[Page 369]]

identified in this paragraph (b) have the meaning given in SAE J1263 or 
J2263 unless specified otherwise.
    (1) The test condition specifications of SAE J1263 apply except as 
follows for wind and road conditions:
    (i) We recommend that you do not perform coastdown testing on days 
for which winds are forecast to exceed 6.0 mi/hr.
    (ii) The grade of the test track or road must not be excessive 
(considering factors such as road safety standards and effects on the 
coastdown results). Road conditions should follow Section 7.4 of SAE 
J1263, except that road grade may exceed 0.5%. If road grade is greater 
than 0.02% over the length of the test surface, you must incorporate 
into the analysis road grade as a function of distance along the length 
of the test surface. Use Section 11.5 of SAE J2263 to calculate the 
force due to grade.
    (2) Operate the vehicle at a top speed above 70 mi/hr, or at its 
maximum achievable speed if it cannot reach 70 mi/hr. If a vehicle is 
equipped with a vehicle speed limiter that is set for a maximum speed 
below 70 mi/hr, you must disable the vehicle speed limiter. Start the 
test at or above 70 mi/hr, or at the vehicle's maximum achievable speed 
if it cannot reach 70 mi/hr. Collect data through a minimum speed at or 
below 15 mi/hr. Data analysis for valid coastdown runs must include the 
range of vehicle speeds specified in this paragraph (b)(2).
    (3) Gather data regarding wind speed and direction, in coordination 
with time-of-day data, using at least one stationary electro-mechanical 
anemometer and suitable data loggers meeting the specifications of SAE 
J1263, as well as the following additional specifications for the 
anemometer placed adjacent to the test surface:
    (i) Calibrate the equipment by running the zero-wind and zero-angle 
calibrations within 24 hours before conducting the coastdown procedures. 
If the coastdown procedures are not complete 24 hours after calibrating 
the equipment, repeat the calibration for another 24 hours of data 
collection.
    (ii) Record the location of the anemometer using a GPS measurement 
device adjacent to the test surface (approximately) at the midway 
distance along the test surface used for coastdowns.
    (iii) Position the anemometer such that it will be at least 2.5 but 
not more than 3.0 vehicle widths from the test vehicle's centerline as 
the test vehicle passes the anemometer.
    (iv) Mount the anemometer at a height that is within 6 inches of 
half the test vehicle's maximum height.
    (v) Place the anemometer at least 50 feet from the nearest tree and 
at least 25 feet from the nearest bush (or equivalent roadside 
features).
    (vi) The height of the grass surrounding the stationary anemometer 
may not exceed 10% of the anemometer's mounted height, within a radius 
equal to the anemometer's mounted height.
    (4) You may split runs as per Section 9.3.1 of SAE J2263, but we 
recommend whole runs. If you split a run, analyze each portion 
separately, but count the split runs as one run with respect to the 
minimum number of runs required.
    (5) You may perform consecutive runs in a single direction, followed 
by consecutive runs in the opposite direction, consistent with good 
engineering judgment. Harmonize starting and stopping points to the 
extent practicable to allow runs to be paired.
    (6) All valid coastdown run times in each direction must be within 
2.0 standard deviations of the mean of the valid coastdown run times 
(from the specified maximum speed down to 15 mi/hr) in that direction. 
Eliminate runs outside this range. After eliminating these runs you must 
have at least eight valid runs in each direction. You may use coastdown 
run times that do not meet these standard deviation requirements if we 
approve it in advance. In your request, describe why the vehicle is not 
able to meet the specified standard deviation requirements and propose 
an alternative set of requirements.
    (7) Analyze data for chassis and post-transmission powerpack testing 
or for use in the GEM simulation tool as follows:
    (i) Follow the procedures specified in Section 10 of SAE J1263 or 
Section 11 of SAE J2263 to calculate coefficients for

[[Page 370]]

chassis and post-transmission powerpack testing.
    (ii) Determine drag area, CdA, as follows instead of 
using the procedure specified in Section 10 of SAE J1263:
    (A) Measure vehicle speed at fixed intervals over the coastdown run 
(generally at 10 Hz), including speeds at or above 15 mi/hr and at or 
below the specified maximum speed. Establish the elevation corresponding 
to each interval as described in SAE J2263 if you need to incorporate 
the effects of road grade.
    (B) Calculate the vehicle's effective mass, Me, in kg by 
adding 56.7 kg to the measured vehicle mass, M, for each tire making 
road contact. This accounts for the rotational inertia of the wheels and 
tires.
    (C) Calculate the road-load force for each measurement interval, 
Fi, using the following equation:
[GRAPHIC] [TIFF OMITTED] TR28AP14.082

Where:

i = an interval counter, starting with i = 1 for the first interval. The 
          designation (i-1) corresponds to the end of the previous 
          interval or, for the first interval, to the start of the test 
          run.
Me = the vehicle's effective mass, expressed to at least the 
          nearest 0.1 kg.
v = vehicle speed at the beginning and end of the measurement interval.
[Delta]t = elapsed time over the measurement interval, in seconds.

    (D) Plot the data from all the coastdown runs on a single plot of 
Fi vs. vi\2\ to determine the slope correlation, 
D, based on the following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.254

Where:

M = the measured vehicle mass, expressed to at least the nearest 0.1 kg.
ag = acceleration of Earth's gravity, as described in 40 CFR 
          1065.630.
[Delta]h = change in elevation over the measurement interval, in m. 
          Assume [Delta]h = 0 if you are not correcting for grade.
[Delta]s = distance the vehicle travels down the road during the 
          measurement interval, in m.
Am = the calculated value of the y-intercept based on the 
          curve-fit.

    (E) Calculate drag area, CdA, in m\2\ using the following 
equation:

[[Page 371]]

[GRAPHIC] [TIFF OMITTED] TR25OC16.255

Where:

r = air density at reference conditions = 1.17 kg/m\3\.
[GRAPHIC] [TIFF OMITTED] TR25OC16.256

T = mean ambient absolute temperature during testing, in K.
P = mean ambient pressuring during the test, in kPa.

    (8) Determine the A, B, and C coefficients identified in Sec.  
1066.210 as follows:
    (i) For chassis and post-transmission powerpack testing, follow the 
procedures specified in Section 10 of SAE J1263 or Section 12 of SAE 
J2263.
    (ii) For the GEM simulation tool, use the following values:

A = Am
B = 0
C = Dadj

[79 FR 23823, Apr. 28, 2016, as amended at 81 FR 74202, Oct. 25, 2016]



Sec.  1066.315  Dynamometer road-load setting.

    Determine dynamometer road-load settings for chassis testing by 
following SAE J2264 (incorporated by reference in Sec.  1066.1010).



    Subpart E_Preparing Vehicles and Running an Exhaust Emission Test



Sec.  1066.401  Overview.

    (a) Use the procedures detailed in this subpart to measure vehicle 
emissions over a specified drive schedule. Different procedures may 
apply for criteria pollutants and greenhouse gas emissions as described 
in the standard-setting part. This subpart describes how to--
    (1) Determine road-load power, test weight, and inertia class.
    (2) Prepare the vehicle, equipment, and measurement instruments for 
an emission test.
    (3) Perform pre-test procedures to verify proper operation of 
certain equipment and analyzers and to prepare them for testing.
    (4) Record pre-test data.
    (5) Sample emissions.
    (6) Record post-test data.
    (7) Perform post-test procedures to verify proper operation of 
certain equipment and analyzers.
    (8) Weigh PM samples.
    (b) The overall test generally consists of prescribed sequences of 
fueling, parking, and driving at specified test conditions. An exhaust 
emission test generally consists of measuring emissions and other 
parameters while a vehicle follows the drive schedules specified in the 
standard-setting part. There are two general types of test cycles:
    (1) Transient cycles. Transient test cycles are typically specified 
in the standard-setting part as a second-by-second sequence of vehicle 
speed commands. Operate a vehicle over a transient cycle such that the 
speed follows the target values. Proportionally sample emissions and 
other parameters and

[[Page 372]]

calculate emission rates as specified in subpart G of this part to 
calculate emissions. The standard-setting part may specify three types 
of transient testing based on the approach to starting the measurement, 
as follows:
    (i) A cold-start transient cycle where you start to measure 
emissions just before starting an engine that has not been warmed up.
    (ii) A hot-start transient cycle where you start to measure 
emissions just before starting a warmed-up engine.
    (iii) A hot-running transient cycle where you start to measure 
emissions after an engine is started, warmed up, and running.
    (2) Cruise cycles. Cruise test cycles are typically specified in the 
standard-setting part as a discrete operating point that has a single 
speed command.
    (i) Start a cruise cycle as a hot-running test, where you start to 
measure emissions after the engine is started and warmed up and the 
vehicle is running at the target test speed.
    (ii) Sample emissions and other parameters for the cruise cycle in 
the same manner as a transient cycle, with the exception that the 
reference speed value is constant. Record instantaneous and mean speed 
values over the cycle.



Sec.  1066.405  Vehicle preparation, preconditioning, and maintenance.

    (a) Prepare the vehicle for testing (including measurement of 
evaporative and refueling emissions if appropriate), as described in the 
standard-setting part.
    (b) If you inspect a vehicle, keep a record of the inspection and 
update your application for certification to document any changes that 
result. You may use any kind of equipment, instrument, or tool that is 
available at dealerships and other service outlets to identify 
malfunctioning components or perform maintenance.
    (c) You may repair defective parts from a test vehicle if they are 
unrelated to emission control. You must ask us to approve repairs that 
might affect the vehicle's emission controls. If we determine that a 
part failure, system malfunction, or associated repair makes the 
vehicle's emission controls unrepresentative of production engines, you 
may not use it as an emission-data vehicle. Also, if the engine 
installed in the test vehicle has a major mechanical failure that 
requires you to take the vehicle apart, you may no longer use the 
vehicle as an emission-data vehicle for exhaust measurements.

[86 FR 34582, June 29, 2021]



Sec.  1066.410  Dynamometer test procedure.

    (a) Dynamometer testing may consist of multiple drive cycles with 
both cold-start and hot-start portions, including prescribed soak times 
before each test interval. The standard-setting part identifies the 
driving schedules and the associated sample intervals, soak periods, 
engine startup and shutdown procedures, and operation of accessories, as 
applicable. Not every test interval includes all these elements.
    (b) Place the vehicle onto the dynamometer without starting the 
engine (for any test cycles) or drive the vehicle onto the dynamometer 
(for hot-start and hot-running cycles only) and position a fan that 
directs cooling air to the vehicle during dynamometer operation as 
described in this paragraph (b). This generally requires squarely 
positioning the fan in front of the vehicle and directing the airflow to 
the vehicle's radiator. Use good engineering judgment to design and 
configure fans to cool the test vehicle in a way that properly simulates 
in-use operation, consistent with the specifications of Sec.  1066.105. 
Except for the following special cases, use a road-speed modulated fan 
meeting the requirements of Sec.  1066.105(c)(2) that is placed within 
90 cm of the front of the vehicle and ensure that the engine compartment 
cover (i.e., hood) is closed:
    (1) For vehicles above 14,000 pounds GVWR, use a fan meeting the 
requirements of Sec.  1066.105(d) that is placed within 90 cm of the 
front of the vehicle and ensure that the engine compartment cover is 
closed.
    (2) For FTP, LA-92, US06, or HFET testing of vehicles at or below 
14,000 pounds GVWR, you may use a fixed-speed fan as specified in the 
following table, with the engine compartment cover open:

[[Page 373]]



    Table 1 of Sec.   1066.410--Fixed-Speed Fan Capacity and Position
       Specifications for Vehicles at or Below 14,000 pounds GVWR
------------------------------------------------------------------------
                                               Approximate distance from
    Test cycle         Maximum fan capacity     the front of the vehicle
------------------------------------------------------------------------
FTP...............  Up to 2.50 m\3\/s........  0 to 30 cm.
US06..............  Up to 7.10 m\3\/s........  0 to 60 cm.
LA-92.............  Up to 7.10 m\3\/s........  0 to 60 cm.
HFET..............  Up to 2.50 m\3\/s........  0 to 30 cm.
------------------------------------------------------------------------

    (3) For SC03 and AC17 testing, use a road-speed modulated fan 
meeting the requirements of Sec.  1066.105(c)(5) that is placed within 
60 to 90 cm of the front of the vehicle and ensure that the engine 
compartment cover is closed. Position the discharge nozzle such that its 
lowest point is not more than 16 cm above the floor of the test cell.
    (c) Record the vehicle's speed trace based on the time and speed 
data from the dynamometer at the recording frequencies given in Table 1 
of Sec.  1066.125. Record speed to at least the nearest 0.01 mi/hr and 
time to at least the nearest 0.1 s.
    (d) You may perform practice runs for operating the vehicle and the 
dynamometer controls to meet the driving tolerances specified in Sec.  
1066.425 or adjust the emission sampling equipment. Verify that the 
accelerator pedal allows for enough control to closely follow the 
prescribed driving schedule. We recommend that you verify your ability 
to meet the minimum dilution factor requirements of Sec.  
1066.110(b)(2)(iii)(B) during these practice runs.
    (e) Inflate tires on drive wheels according to the vehicle 
manufacturer's specifications. The tire pressure for drive wheels must 
be the same for dynamometer operation and for dynamometer coastdown 
procedures used for determining road-load coefficients. Report these 
measured tire pressure values with the test results.
    (f) Tie down or load the test vehicle as needed to provide a normal 
force at the tire and dynamometer roll interface to prevent wheel slip. 
For vehicles above 14,000 pounds GVWR, report this measured force with 
the test results.
    (g) Use good engineering judgment when testing vehicles in four-
wheel drive or all-wheel drive mode. (For purposes of this paragraph 
(g), the term four-wheel drive includes other multiple drive-axle 
configurations.) This may involve testing on a dynamometer with a 
separate dynamometer roll for each drive axle; or two drive axles may 
use a single roll, as described in Sec.  1066.210(d)(1); or you may 
deactivate the second set of drive wheels and operate the vehicle on a 
single roll. For all vehicles at or below 14,000 GVWR, we will test your 
vehicle using the same dynamometer roll arrangement that you used. We 
may also test your vehicle using another dynamometer roll arrangement 
for information-gathering purposes. If we choose to perform additional 
testing that requires vehicle modifications, we will ask you to 
configure the vehicle appropriately.
    (h) Determine equivalent test weight as follows:
    (1) For vehicles at or below 14,000 pounds GVWR, determine ETW as 
described in Sec.  1066.805. Set dynamometer vehicle inertia, I, based 
on dynamometer type, as follows:
    (i) For two-wheel drive dynamometers, set I = ETW.
    (ii) For four-wheel drive dynamometers, set I = 0.985 [middot] ETW.
    (2) For vehicles above 14,000 pounds GVWR, determine the vehicle's 
effective mass as described in Sec.  1066.310 and use this as the test 
weight.
    (i) Warm up the dynamometer as recommended by the dynamometer 
manufacturer.
    (j) Following the test, determine the actual driving distance by 
counting the number of dynamometer roll or shaft revolutions, or by 
integrating speed over the course of testing from a high-resolution 
encoder system.

[79 FR 23823, Apr. 28, 2014, as amended at 80 FR 9121, Feb. 19, 2015; 81 
FR 74202, Oct. 25, 2016]



Sec.  1066.415  Vehicle operation.

    This section describes how to test a conventionally configured 
vehicle (vehicles with transmission shifters, foot pedal accelerators, 
etc). You may ask us to modify these procedures for vehicles that do not 
have these control features.
    (a) Start the vehicle as follows:

[[Page 374]]

    (1) At the beginning of the test cycle, start the vehicle according 
to the procedure described in the owners manual. In the case of HEVs, 
this would generally involve activating vehicle systems such that the 
engine will start when the vehicle's control algorithms determine that 
the engine should provide power instead of or in addition to power from 
the rechargeable energy storage system (RESS). Unless we specify 
otherwise, engine starting throughout this part generally refers to this 
step of activating the system on HEVs, whether or not that causes the 
engine to start running.
    (2) Place the transmission in gear as described by the test cycle in 
the standard-setting part. During idle operation, apply the brakes if 
necessary to keep the drive wheels from turning.
    (b) If the vehicle does not start after your recommended maximum 
cranking time, wait and restart cranking according to your recommended 
practice. If you do not recommend such a cranking procedure, stop 
cranking after 10 seconds, wait for 10 seconds, then start cranking 
again for up to 10 seconds. You may repeat this for up to three start 
attempts. If the vehicle does not start after three attempts, you must 
determine and record the reason for failure to start. Shut off sampling 
systems and either turn the CVS off or disconnect the laboratory exhaust 
tubing from the tailpipe during the diagnostic period to prevent flow 
through the exhaust system. Reschedule the vehicle for testing. This may 
require performing vehicle preparation and preconditioning if the 
testing needs to be rerun from a cold start. If failure to start occurs 
during a hot-start test, you may reschedule the hot-start test without 
repeating the cold-start test, as long as you bring the vehicle to a 
hot-start condition before starting the hot-start test.
    (c) Repeat the recommended starting procedure if the engine has a 
false start (i.e., an incomplete start).
    (d) Take the following steps if the engine stalls:
    (1) If the engine stalls during an idle period, restart the engine 
immediately and continue the test. If you cannot restart the engine soon 
enough to allow the vehicle to follow the next acceleration, stop the 
driving schedule indicator and reactivate it when the vehicle restarts.
    (2) Void the test if the vehicle stalls during vehicle operation. If 
this happens, remove the vehicle from the dynamometer, take corrective 
action, and reschedule the vehicle for testing. Record the reason for 
the malfunction (if determined) and any corrective action. See the 
standard-setting part for instructions about reporting these 
malfunctions.
    (e) Operate vehicles during testing as follows:
    (1) Where we do not give specific instructions, operate the vehicle 
according to the recommendations in the owners manual, unless those 
recommendations are unrepresentative of what may reasonably be expected 
for in-use operation.
    (2) If vehicles have features that preclude dynamometer testing, you 
may modify these features as necessary to allow testing, consistent with 
good engineering judgment, as long as it does not affect your ability to 
demonstrate that your vehicles comply with the applicable standards in 
this chapter. Send us written notification describing these changes 
along with supporting rationale.
    (3) Operate vehicles during idle as follows:
    (i) For vehicles with automatic transmission, operate at idle with 
the transmission in ``Drive'' with the wheels braked, except that you 
may shift to ``Neutral'' for the first idle period and for any idle 
period longer than one minute. If you put the vehicle in ``Neutral'' 
during an idle, you must shift the vehicle into ``Drive'' with the 
wheels braked at least 5 seconds before the end of the idle period. Note 
that this does not preclude vehicle designs involving engine shutdown 
during idle.
    (ii) For vehicles with manual transmission, operate at idle with the 
transmission in gear with the clutch disengaged, except that you may 
shift to ``Neutral'' with the clutch engaged for the first idle period 
and for any idle period longer than one minute. If you put the vehicle 
in ``Neutral'' during idle, you must shift to first gear with the clutch 
disengaged at least 5 seconds before the end of the idle period. Note

[[Page 375]]

that this does not preclude vehicle designs involving engine operation 
with shutdown during idle.
    (4) Operate the vehicle with the appropriate accelerator pedal 
movement necessary to follow the scheduled speeds in the driving 
schedule. Avoid smoothing speed variations and unnecessary movement of 
the accelerator pedal.
    (5) Operate the vehicle smoothly, following representative shift 
speeds and procedures. For manual transmissions, the operator shall 
release the accelerator pedal during each shift and accomplish the shift 
without delay. If the vehicle cannot accelerate at the specified rate, 
operate it at maximum available power until the vehicle speed reaches 
the value prescribed in the driving schedule.
    (6) Decelerate as follows:
    (i) For vehicles with automatic transmission, use the brakes or 
accelerator pedal as necessary, without manually changing gears, to 
maintain the desired speed.
    (ii) For vehicles with manual transmission, shift gears in a way 
that represents reasonable shift patterns for in-use operation, 
considering vehicle speed, engine speed, and any other relevant 
variables. Disengage the clutch when the speed drops below 15 mi/hr, 
when engine roughness is evident, or when good engineering judgment 
indicates the engine is likely to stall. Manufacturers may recommend 
shift guidance in the owners manual that differs from the shift schedule 
used during testing, as long as both shift schedules are described in 
the application for certification; in this case, we may shift during 
testing as described in the owners manual.

[79 FR 23823, Apr. 28, 2016, as amended at 81 FR 74202, Oct. 25, 2016; 
88 FR 4708, Jan. 24, 2023]



Sec.  1066.420  Test preparation.

    (a) Follow the procedures for PM sample preconditioning and tare 
weighing as described in 40 CFR 1065.590 if you need to measure PM 
emissions.
    (b) Minimize the effect of nonmethane hydrocarbon contamination in 
the hydrocarbon sampling system for vehicles with compression-ignition 
engines as follows:
    (1) For vehicles at or below 14,000 pounds GVWR, account for 
contamination using one of the following methods:
    (i) Introduce zero and span gas during analyzer calibration using 
one of the following methods, noting that the hydrocarbon analyzer flow 
rate and pressure during zero and span calibration (and background bag 
reading) must be exactly the same as that used during testing to 
minimize measurement errors:
    (A) Close off the hydrocarbon sampling system sample probe and 
introduce gases downstream of the probe making sure that you do not 
pressurize the system.
    (B) Introduce zero and span gas directly at the hydrocarbon sampling 
system probe at a flow rate greater than 125% of the hydrocarbon 
analyzer flow rate allowing some gas to exit probe inlet.
    (ii) Perform the contamination verification in paragraph (b)(2) of 
this section, except use 0.5 [micro]mol/mol in 40 CFR 
1065.520(f)(8)(iii).
    (2) For vehicles above 14,000 pounds GVWR, verify the amount of 
nonmethane hydrocarbon contamination as described in 40 CFR 1065.520(f).
    (c) Unless the standard-setting part specifies different tolerances, 
verify at some point before the test that ambient conditions are within 
the tolerances specified in this paragraph (c). For purposes of this 
paragraph (c), ``before the test'' means any time from a point just 
prior to engine starting (excluding engine restarts) to the point at 
which emission sampling begins.
    (1) Ambient temperature must be (20 to 30) [deg]C. See Sec.  
1066.425(h) for circumstances under which ambient temperatures must 
remain within this range during the test.
    (2) Dilution air conditions must meet the specifications in Sec.  
1066.110(b)(2). We recommend verifying dilution air conditions just 
before starting each test interval.
    (d) Control test cell ambient air humidity as follows:
    (1) For vehicles at or below 14,000 pounds GVWR, follow the humidity 
requirements in Table 1 of this section, unless the standard-setting 
part specifies otherwise. When complying with

[[Page 376]]

humidity requirements in Table 1, where no tolerance is specified, use 
good engineering judgment to maintain the humidity level near the 
specified value within the limitations of your test facility.
    (2) For vehicles above 14,000 pounds GVWR, you may test vehicles at 
any humidity.
    (3) Table 1 follows:

       Table 1 of Sec.   1066.420--Test Cell Humidity Requirements
------------------------------------------------------------------------
                                       Humidity
                                      requirement     Tolerance (grains
            Test cycle                (grains H2O     H2O per pound dry
                                     per pound dry          air)
                                         air)
------------------------------------------------------------------------
AC17..............................              69  5 average, 10
                                                     instantaneous.
FTP \a\ and LA-92.................              50
HFET..............................              50
SC03..............................             100  5 average.
US06..............................              50
------------------------------------------------------------------------
\a\ FTP humidity requirement does not apply for cold (-7 [deg]C),
  intermediate (10 [deg]C), and hot (35 [deg]C) temperature testing.

    (e) You may perform a final calibration of proportional-flow control 
systems, which may include performing practice runs.
    (f) You may perform the following procedure to precondition sampling 
systems:
    (1) Operate the vehicle over the test cycle.
    (2) Operate any dilution systems at their expected flow rates. 
Prevent aqueous condensation in the dilution systems as described in 40 
CFR 1065.140(c)(6), taking into account allowances given in Sec.  
1066.110(b)(2)(iv).
    (3) Operate any PM sampling systems at their expected flow rates.
    (4) Sample PM using any sample media. You may change sample media 
during preconditioning. You must discard preconditioning samples without 
weighing them.
    (5) You may purge any gaseous sampling systems during 
preconditioning.
    (6) You may conduct calibrations or verifications on any idle 
equipment or analyzers during preconditioning.
    (g) Take the following steps before emission sampling begins:
    (1) For batch sampling, connect clean storage media, such as 
evacuated bags or tare-weighed filters.
    (2) Start all measurement instruments according to the instrument 
manufacturer's instructions and using good engineering judgment.
    (3) Start dilution systems, sample pumps, and the data-collection 
system.
    (4) Pre-heat or pre-cool heat exchangers in the sampling system to 
within their operating temperature tolerances for a test.
    (5) Allow heated or cooled components such as sample lines, filters, 
chillers, and pumps to stabilize at their operating temperatures.
    (6) Adjust the sample flow rates to desired levels using bypass 
flow, if desired.
    (7) Zero or re-zero any electronic integrating devices before the 
start of any test interval.
    (8) Select gas analyzer ranges. You may not switch the gain of an 
analyzer's analog operational amplifier(s) during a test. However, you 
may switch (automatically or manually) gas analyzer ranges during a test 
if such switching changes only the range over which the digital 
resolution of the instrument is applied. For batch analyzers, select 
ranges before final bag analysis.
    (9) Zero and span all continuous gas analyzers using gases that meet 
the specifications of 40 CFR 1065.750. For FID analyzers, you may 
account for the carbon number of your span gas either during the 
calibration process or when calculating your final emission value. For 
example, if you use a C3H8 span gas of 
concentration 200 ppm ([micro]mol/mol), you may span the FID to respond 
with a value of 600 ppm ([micro]mol/mol) of carbon or 200 ppm of 
propane. However, if your FID response is equivalent to propane, include 
a factor of three to make the final calculated hydrocarbon mass 
consistent with a molar mass of 13.875389. When utilizing an NMC-FID, 
span the FID analyzer consistent with the determination of their 
respective response factors, RF, and penetration fractions, PF, 
according to 40 CFR 1065.365.
    (10) We recommend that you verify gas analyzer responses after 
zeroing and spanning by sampling a calibration gas that has a 
concentration near one-half of the span gas concentration. Based on the 
results, use good engineering judgment to decide whether or

[[Page 377]]

not to re-zero, re-span, or re-calibrate a gas analyzer before starting 
a test.
    (11) If you correct for dilution air background concentrations of 
associated engine exhaust constituents, start sampling and recording 
background concentrations at the same time you start sampling exhaust 
gases.
    (12) Turn on cooling fans immediately before starting the test.
    (h) Proceed with the test sequence described in Sec.  1066.425.

[79 FR 23823, Apr. 28, 2014, as amended at 80 FR 9121, Feb. 19, 2015; 86 
FR 34582, June 29, 2021; 88 FR 4708, Jan. 24, 2023]



Sec.  1066.425  Performing emission tests.

    (a) See the standard-setting part for drive schedules. These are 
defined by a smooth fit of a specified speed vs. time sequence.
    (b) The driver must attempt to follow the target schedule as closely 
as possible, consistent with the specifications in paragraph (b) of this 
section. Instantaneous speeds must stay within the following tolerances:
    (1) The upper limit is 2.0 mi/hr higher than the highest point on 
the trace within 1.0 s of the given point in time.
    (2) The lower limit is 2.0 mi/hr lower than the lowest point on the 
trace within 1.0 s of the given time.
    (3) The same limits apply for vehicle operation without exhaust 
measurements, such as vehicle preconditioning and warm-up, except that 
the upper and lower limits for speed values are 4.0 mi/hr. In addition, up to three occurrences of speed 
variations greater than the tolerance are acceptable for vehicle 
operation in which no exhaust emission standards apply, as long as they 
occur for less than 15 seconds on any occasion and are clearly 
documented as to the time and speed at that point of the driving 
schedule.
    (4) Void the test if you do not maintain speed values as specified 
in this paragraph (b), except as allowed by this paragraph (b)(4). Speed 
variations (such as may occur during gear changes or braking spikes) may 
occur as follows, as long as such variations are clearly documented, 
including the time and speed values and the reason for the deviation:
    (i) Speed variations greater than the specified limits are 
acceptable for up to 2.0 seconds on any occasion.
    (ii) For vehicles that are not able to maintain acceleration as 
specified in Sec.  1066.415(e)(5), do not count the insufficient 
acceleration as being outside the specified limits.
    (5) We may approve an alternate test cycle and cycle-validation 
criteria for vehicles that do not have enough power to follow the 
specified driving trace. The alternate driving specifications must be 
based on making best efforts to maintain acceleration and speed to 
follow the specified test cycle. We must approve these alternate driving 
specifications before you perform this testing.
    (c) Figure 1 and Figure 2 of this section show the range of 
acceptable speed tolerances for typical points during testing. Figure 1 
of this section is typical of portions of the speed curve that are 
increasing or decreasing throughout the 2-second time interval. Figure 2 
of this section is typical of portions of the speed curve that include a 
maximum or minimum value.

[[Page 378]]

[GRAPHIC] [TIFF OMITTED] TR28AP14.086

[GRAPHIC] [TIFF OMITTED] TR28AP14.087

    (d) Start testing as follows:
    (1) If a vehicle is already running and warmed up, and starting is 
not part of the test cycle, operate the vehicle as follows:

[[Page 379]]

    (i) For transient test cycles, control vehicle speeds to follow a 
drive schedule consisting of a series of idles, accelerations, cruises, 
and decelerations.
    (ii) For cruise test cycles, control the vehicle operation to match 
the speed of the first interval of the test cycle. Follow the 
instructions in the standard-setting part to determine how long to 
stabilize the vehicle during each interval, how long to sample emissions 
at each interval, and how to transition between intervals.
    (2) If engine starting is part of the test cycle, start recording 
continuous data, turn on any electronic integrating devices, and start 
batch sampling before starting the engine. Initiate the driver's trace 
when the engine starts.
    (e) Perform the following at the end of each test interval, except 
as specified in standard-setting part:
    (1) Shut down the vehicle if it is part of the test cycle or if 
testing is complete.
    (2) Continue to operate all sampling and dilution systems to allow 
the response times to elapse. Then stop all sampling and recording, 
including background sampling. Finally, stop any integrating devices and 
indicate the end of the duty cycle in the recorded data.
    (f) If testing involves engine shutdown followed by another test 
interval, start a timer for the vehicle soak when the engine shuts down. 
Turn off cooling fans, close the engine compartment cover (if 
applicable), and turn off the CVS or disconnect the exhaust tube from 
the vehicle's tailpipe(s) unless otherwise instructed in the standard-
setting part. If testing is complete, disconnect the laboratory exhaust 
tubing from the vehicle's tailpipe(s) and drive the vehicle from the 
dynamometer.
    (g) Take the following steps after emission sampling is complete:
    (1) For any proportional batch sample, such as a bag sample or PM 
sample, verify that proportional sampling was maintained according to 40 
CFR 1065.545. Void any samples that did not maintain proportional 
sampling according to those specifications.
    (2) Place any used PM samples into covered or sealed containers and 
return them to the PM-stabilization environment. Follow the PM sample 
post-conditioning and total weighing procedures in 40 CFR 1065.595.
    (3) As soon as practical after the interval or test cycle is 
complete, or optionally during the soak period if practical, perform the 
following:
    (i) Begin drift check for all continuous gas analyzers as described 
in paragraph (g)(5) of this section and zero and span all batch gas 
analyzers as soon as practical before any batch sample analysis. You may 
perform this batch analyzer zero and span before the end of the test 
interval.
    (ii) Analyze any conventional gaseous batch samples (HC, 
CH4, CO, NOX, and CO2) no later than 30 
minutes after a test interval is complete, or during the soak period if 
practical. Analyze background samples no later than 60 minutes after the 
test interval is complete.
    (iii) Analyze nonconventional gaseous batch samples (including 
background), such as NMHCE, N2O, or NMOG sampling with 
ethanol, as soon as practicable using good engineering judgment.
    (4) If an analyzer operated above 100% of its range at any time 
during the test, perform the following steps:
    (i) For batch sampling, re-analyze the sample using the lowest 
analyzer range that results in a maximum instrument response below 100%. 
Report the result from the lowest range from which the analyzer operates 
below 100% of its range.
    (ii) For continuous sampling, repeat the entire test using the next 
higher analyzer range. If the analyzer again operates above 100% of its 
range, repeat the test using the next higher range. Continue to repeat 
the test until the analyzer consistently operates at less than 100% of 
its range. Keep records of any tests where the analyzer exceeds its 
range. We may consider these results to determine that the test vehicle 
exceeded an emission standard, consistent with good engineering 
judgment.
    (5) After quantifying exhaust gases, verify drift as follows:
    (i) For batch and continuous gas analyzers, record the mean analyzer 
value after stabilizing a zero gas to the analyzer. Stabilization may 
include time

[[Page 380]]

to purge the analyzer of any sample gas, plus any additional time to 
account for analyzer response.
    (ii) Record the mean analyzer value after stabilizing the span gas 
to the analyzer. Stabilization may include time to purge the analyzer of 
any sample gas, plus any additional time to account for analyzer 
response.
    (iii) Use these data to verify that analyzer drift does not exceed 
2.0% of the analyzer full scale.
    (h) Measure and record ambient pressure. Measure and record ambient 
temperature continuously to verify that it remains within the 
temperature range specified in Sec.  1066.420(c)(1) throughout the test. 
Also measure humidity if required, such as for correcting NOX 
emissions, or meeting the requirements of Sec.  1066.420(d).
    (i) [Reserved]
    (j) For vehicles at or below 14,000 pounds GVWR, determine overall 
driver accuracy as follows:
    (1) Compare the following drive-cycle metrics, based on measured 
vehicle speeds, to a reference value based on the target cycle that 
would have been generated by driving exactly to the target trace as 
described in SAE J2951 (incorporated by reference in Sec.  1066.1010):
    (i) Determine the Energy Economy Rating as described in Section 5.4 
of SAE J2951.
    (ii) Determine the Absolute Speed Change Rating as described in 
Section 5.5 of SAE J2951.
    (iii) Determine the Inertia Work Rating as described in Section 5.6 
of SAE J2951.
    (iv) Determine the phase-weighted composite Energy Based Drive 
Metrics for the criteria specified in this paragraph (j)(1) as described 
in Section 5.7 of SAE J2951.
    (2) The standard-setting part may require you to give us 10 Hz data 
to characterize both target and actual values for cycle energy. 
Calculate target values based on the vehicles speeds from the specified 
test cycle.

[79 FR 23823, Apr. 28, 2016, as amended at 81 FR 74203, Oct. 25, 2016]



        Subpart F_Electric Vehicles and Hybrid Electric Vehicles



Sec.  1066.501  Overview.

    Use the following procedures to test EVs and HEVs (including PHEVs):
    (a) Correct the results for Net Energy Change of the RESS as 
follows:
    (1) For all sizes of EVs, follow SAE J1634 (incorporated by 
reference in Sec.  1066.1010).
    (2) For HEVs at or below 14,000 pounds GVWR, follow SAE J1711 
(incorporated by reference in Sec.  1066.1010) except as described in 
this paragraph (a). Disregard provisions of SAE J1711 that differ from 
this part or the standard-setting part if they are not specific to HEVs. 
Apply the following adjustments and clarifications to SAE J1711:
    (i) If the procedure calls for charge-sustaining operation, start 
the drive with a State of Charge that is appropriate to ensure charge-
sustaining operation for the duration of the drive. Take steps other 
than emission measurements to confirm that vehicles are in charge-
sustaining mode for the duration of the drive.
    (ii) We may approve the use of the alternate End-of-Test criterion 
in Section 3.9.1 of SAE J1711 for charge-depleting tests and the Net 
Energy Change correction in Appendix C of SAE J1711 for charge-
sustaining tests if the specified criterion and correction are 
insufficient or inappropriate.
    (iii) For charge-sustaining tests Appendix C of SAE J1711 may be 
used to correct final fuel economy values, CO2 emissions, and 
carbon-related exhaust emissions, but may not be used to correct 
measured values for criteria pollutant emissions.
    (iv) You may test subject to a measurement accuracy of 0.3% of full scale in place of the measurement accuracy 
specified in Section 4.2a of SAE J1711.
    (3) For HEVs above 14,000 pounds GVWR, follow SAE J2711 
(incorporated by reference in Sec.  1066.1010) for requirements related 
to charge-sustaining operation.
    (4) Use an integration frequency of 1 to 20 Hz for power analyzers 
to verify compliance with current and voltage specifications.
    (b) This paragraph (b) applies for vehicles that include an engine-
powered

[[Page 381]]

generator or other auxiliary power unit that provides motive power. For 
example, this would include a vehicle that has a small gasoline engine 
that generates electricity to charge batteries. Unless we approve 
otherwise, measure emissions for all test cycles when such an engine is 
operating. For each test cycle for which emissions are not measured, you 
must validate that such engines are not operating at any time during the 
test cycle.
    (c) You may stop emission sampling anytime the engine is turned off, 
consistent with good engineering judgment. This is intended to allow for 
higher concentrations of dilute exhaust gases and more accurate 
measurements. Take steps to account for exhaust transport delay in the 
sampling system, and be sure to integrate over the actual sampling 
duration when determining Vmix.

[79 FR 23823, Apr. 28, 2014, as amended at 80 FR 9121, Feb. 19, 2015]



                         Subpart G_Calculations



Sec.  1066.601  Overview.

    (a) This subpart describes calculations used to determine emission 
rates. See the standard-setting part and the other provisions of this 
part to determine which equations apply for your testing. This subpart 
describes how to--
    (1) Use the signals recorded before, during, and after an emission 
test to calculate distance-specific emissions of each regulated 
pollutant.
    (2) Perform calculations for calibrations and performance checks.
    (3) Determine statistical values.
    (b) You may use data from multiple systems to calculate test results 
for a single emission test, consistent with good engineering judgment. 
You may also make multiple measurements from a single batch sample, such 
as multiple weighing of a PM filter or multiple readings from a bag 
sample. Although you may use an average of multiple measurements from a 
single test, you may not use test results from multiple emission tests 
to report emissions. We allow weighted means where appropriate, such as 
for sampling onto a PM filter over the FTP. You may discard statistical 
outliers, but you must report all results.



Sec.  1066.605  Mass-based and molar-based exhaust emission calculations.

    (a) Calculate your total mass of emissions over a test cycle as 
specified in paragraph (c) of this section or in 40 CFR part 1065, 
subpart G, as applicable.
    (b) See the standard-setting part for composite emission 
calculations over multiple test intervals and the corresponding 
weighting factors.
    (c) Perform the following sequence of preliminary calculations to 
correct recorded concentration measurements before calculating mass 
emissions in paragraphs (e) and (f) of this section:
    (1) For vehicles above 14,000 pounds GVWR, correct all THC and 
CH4 concentrations for initial contamination as described in 
40 CFR 1065.660(a), including continuous readings, sample bag readings, 
and dilution air background readings. This correction is optional for 
vehicles at or below 14,000 pounds GVWR.
    (2) Correct all concentrations measured on a ``dry'' basis to a 
``wet'' basis, including dilution air background concentrations.
    (3) Calculate all NMHC and CH4 concentrations, including 
dilution air background concentrations, as described in 40 CFR 1065.660.
    (4) For vehicles at or below 14,000 pounds GVWR, calculate HC 
concentrations, including dilution air background concentrations, as 
described in this section, and as described in Sec.  1066.635 for NMOG. 
For emission testing of vehicles above 14,000 pounds GVWR, with fuels 
that contain 25% or more oxygenated compounds by volume, calculate THCE 
and NMHCE concentrations, including dilution air background 
concentrations, as described in 40 CFR part 1065, subpart I.
    (5) Correct all gaseous concentrations for dilution air background 
as described in Sec.  1066.610.
    (6) Correct NOX emission values for intake-air humidity 
as described in Sec.  1066.615.
    (7) Correct all PM filter masses for sample media buoyancy as 
described in 40 CFR 1065.690.
    (d) Calculate g/mile emission rates using the following equation 
unless the

[[Page 382]]

standard-setting part specifies otherwise:
[GRAPHIC] [TIFF OMITTED] TR25OC16.257

Where:

e[emission] = emission rate over the test interval.
m[emission] = emission mass over the test interval.
D = the measured driving distance over the test interval.

    Example: 
mNOx = 0.3177 g
DHFET = 10.19 miles
[GRAPHIC] [TIFF OMITTED] TR25OC16.258

    (e) Calculate the emission mass of each gaseous pollutant using the 
following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.259

Where:

m[emission] = emission mass over the test interval.
Vmix = total dilute exhaust volume over the test interval, 
          corrected to standard reference conditions, and corrected for 
          any volume removed for emission sampling and for any volume 
          change from adding secondary dilution air.
p[emission] = density of the appropriate chemical species as 
          given in Sec.  1066.1005(f).
x[emission] = measured emission concentration in the sample, 
          after dry-to-wet and background corrections.
c = 10-2 for emission concentrations in %, and 
          10-6 for emission concentrations in ppm.

    Example: 
Vmix = 170.878 m\3\ (from paragraph (f) of this section)
rNOx = 1913 g/m\3\
xNOx = 0.9721 ppm
c = 10-6
mNOx = 
          170.878[middot]1913[middot]0.9721[middot]10-6 = 
          0.3177 g

    (f) Calculation of the emission mass of PM, mPM, is 
dependent on how many PM filters you use, as follows:
    (1) Except as otherwise specified in this paragraph (f), calculate 
mPM using the following equation:

[[Page 383]]

[GRAPHIC] [TIFF OMITTED] TR25OC16.260

Where:

mPM = mass of particulate matter emissions over the test 
          interval, as described in Sec.  1066.815(b)(1), (2), and (3).
Vmix = total dilute exhaust volume over the test interval, 
          corrected to standard reference conditions, and corrected for 
          any volume removed for emission sampling and for any volume 
          change from adding secondary dilution air. For partial-flow 
          dilution systems, set Vmix equal to the total 
          exhaust volume over the test interval, corrected to standard 
          reference conditions.
VPMstd = total volume of dilute exhaust sampled through the 
          filter over the test interval, corrected to standard reference 
          conditions.
Vsdastd = total volume of secondary dilution air sampled 
          through the filter over the test interval, corrected to 
          standard reference conditions. For partial-flow dilution 
          systems, set Vsdastd equal to total dilution air 
          volume over the test interval, corrected to standard reference 
          conditions.
mPMfil = mass of particulate matter emissions on the filter 
          over the test interval.
mPMbkgnd = mass of particulate matter on the background 
          filter.

    Example: 
Vmix = 170.878 m\3\ (from paragraph (g) of this section)
VPMstd = 0.925 m\3\ (from paragraph (g) of this section)
Vsdastd = 0.527 m\3\ (from paragraph (g) of this section)
mPMfil = 0.0000045 g
mPMbkgnd = 0.0000014 g
[GRAPHIC] [TIFF OMITTED] TR25OC16.261

    (2) If you sample PM onto a single filter as described in Sec.  
1066.815(b)(4)(i) or (b)(4)(ii) (for constant volume samplers), 
calculate mPM using the following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.262

Where:

mPM = mass of particulate matter emissions over the entire 
          FTP.
Vmix = total dilute exhaust volume over the test interval, 
          corrected to standard reference conditions, and corrected for 
          any volume removed for emission sampling and for any volume 
          change from adding secondary dilution air.
V[interval]-PMstd = total volume of dilute exhaust sampled 
          through the filter over the test interval (ct = cold 
          transient, s = stabilized, ht = hot transient), corrected to 
          standard reference conditions.

[[Page 384]]

V[interval]-sdastd = total volume of secondary dilution air 
          sampled through the filter over the test interval (ct = cold 
          transient, s = stabilized, ht = hot transient), corrected to 
          standard reference conditions.
mPMfil = mass of particulate matter emissions on the filter 
          over the test interval.
mPMbkgnd = mass of particulate matter on the background 
          filter over the test interval.

    Example: 
Vmix = 633.691 m\3\
Vct-PMstd = 0.925 m\3\
Vct-sdastd = 0.527 m\3\
Vs-PMstd = 1.967 m\3\
Vs-sdastd = 1.121 m\3\
Vht-PMstd = 1.122 m\3\
Vht-sdastd = 0.639 m\3\
mPMfil = 0.0000106 g
mPMbkgnd = 0.0000014 g
[GRAPHIC] [TIFF OMITTED] TR25OC16.263

mPM = 0.00222 g

    (3) If you sample PM onto a single filter as described in Sec.  
1066.815(b)(4)(ii) (for partial flow dilution systems), calculate 
mPM using the following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.264

Where:

mPM = mass of particulate matter emissions over the entire 
          FTP.
V[interval]-exhstd = total engine exhaust volume over the 
          test interval (ct = cold transient, s = stabilized, ht = hot 
          transient), corrected to standard reference conditions, and 
          corrected for any volume removed for emission sampling.
V[interval]-PMstd = total volume of dilute exhaust sampled 
          through the filter over the test interval (ct = cold 
          transient, s = stabilized, ht = hot transient), corrected to 
          standard reference conditions.
V[interval]-dilstd = total volume of dilution air over the 
          test interval (ct = cold transient, s = stabilized, ht = hot 
          transient), corrected to standard reference conditions and for 
          any volume removed for emission sampling.
mPMfil = mass of particulate matter emissions on the filter 
          over the test interval.
mPMbkgnd = mass of particulate matter on the background 
          filter over the test interval.

    Example: 
Vct-exhstd = 5.55 m\3\
Vct-PMstd = 0.526 m\3\
Vct-dilstd = 0.481 m\3\
Vs-exhstd = 9.53 m\3\
Vs-PMstd = 0.903 m\3\
Vs-dilstd = 0.857 m\3\
Vht-exhstd = 5.54 m\3\
Vht-PMstd = 0.527 m\3\
Vht-dilstd = 0.489 m\3\
mPMfil = 0.0000106 g
mPMbkgnd = 0.0000014 g

[[Page 385]]

[GRAPHIC] [TIFF OMITTED] TR25OC16.265

mPM = 0.00269 g

    (4) If you sample PM onto a single filter as described in Sec.  
1066.815(b)(5)(i) or (b)(5)(ii) (for constant volume samplers), 
calculate mPM using the following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.266

Where:

mPM = mass of particulate matter emissions over the entire 
          FTP.
Vmix = total dilute exhaust volume over the test interval, 
          corrected to standard reference conditions, and corrected for 
          any volume removed for emission sampling and for any volume 
          change from secondary dilution air.
V[interval]-PMstd = total volume of dilute exhaust sampled 
          through the filter over the test interval (ct = cold 
          transient, cs = cold stabilized, ht = hot transient, hs = hot 
          stabilized), corrected to standard reference conditions.
V[interval]-sdastd = total volume of secondary dilution air 
          sampled through the filter over the test interval (ct = cold 
          transient, cs = cold stabilized, ht = hot transient, hs = hot 
          stabilized), corrected to standard reference conditions.
mPMfil = mass of particulate matter emissions on the filter 
          over the test interval.
mPMbkgnd = mass of particulate matter on the background 
          filter over the test interval.

    Example: 
Vmix = 972.121 m\3\
Vct-PMstd = 0.925 m\3\
Vct-sdastd = 0.529 m\3\
Vcs-PMstd = 1.968 m\3\
Vcs-sdastd = 1.123 m\3\
Vht-PMstd = 1.122 m\3\
Vht-sdastd = 0.641 m\3\
Vhs-PMstd = 1.967 m\3\
Vhs-sdastd = 1.121 m\3\
mPMfil = 0.0000229 g
mPMbkgnd = 0.0000014 g
[GRAPHIC] [TIFF OMITTED] TR25OC16.267

mPM = 0.00401 g

    (5) If you sample PM onto a single filter as described in Sec.  
1066.815(b)(5)(ii) (for partial flow dilution systems), calculate 
mPM using the following equation:

[[Page 386]]

[GRAPHIC] [TIFF OMITTED] TR25OC16.268

Where:

mPM = mass of particulate matter emissions over the entire 
          FTP.
V[interval]-exhstd = total engine exhaust volume over the 
          test interval (ct = cold transient, cs = cold stabilized, ht = 
          hot transient, hs = hot stabilized), corrected to standard 
          reference conditions, and corrected for any volume removed for 
          emission sampling.
V[interval]-PMstd = total volume of dilute exhaust sampled 
          through the filter over the test interval (ct = cold 
          transient, cs = cold stabilized, ht = hot transient, hs = hot 
          stabilized), corrected to standard reference conditions.
V[interval]-dilstd = total volume of dilution air over the 
          test interval (ct = cold transient, cs = cold stabilized, ht = 
          hot transient, hs = hot stabilized), corrected to standard 
          reference conditions and for any volume removed for emission 
          sampling.
mPMfil = mass of particulate matter emissions on the filter 
          over the test interval.
mPMbkgnd = mass of particulate matter on the background 
          filter over the test interval.

    Example: 
Vct-exhstd = 5.55 m\3\
Vct-PMstd = 0.526 m\3\
Vct-dilstd = 0.481 m\3\
Vcs-exhstd = 9.53 m\3\
Vcs-PMstd = 0.903 m\3\
Vcs-dilstd = 0.857 m\3\
Vht-exhstd = 5.54 m\3\
Vht-PMstd = 0.527 m\3\
Vht-dilstd = 0.489 m\3\
Vhs-exhstd = 9.54 m\3\
Vhs-PMstd = 0.902 m\3\
Vhs-dilstd = 0.856 m\3\
mPMfil = 0.0000229 g
mPMbkgnd = 0.0000014 g
[GRAPHIC] [TIFF OMITTED] TR25OC16.269

mPM = 0.00266 g

    (g) This paragraph (g) describes how to correct flow and flow rates 
to standard reference conditions and provides an example for determining 
Vmix based on CVS total flow and the removal of sample flow 
from the dilute exhaust gas. You may use predetermined nominal values 
for removed sample volumes, except for flows used for batch sampling.
    (1) Correct flow and flow rates to standard reference conditions as 
needed using the following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.270


[[Page 387]]


Where:

V[flow]std = total flow volume at the flow meter, corrected 
          to standard reference conditions.
V[flow]act = total flow volume at the flow meter at test 
          conditions.
pin = absolute static pressure at the flow meter inlet, 
          measured directly or calculated as the sum of atmospheric 
          pressure plus a differential pressure referenced to 
          atmospheric pressure.
Tstd = standard temperature.
pstd = standard pressure.
Tin = temperature of the dilute exhaust sample at the flow 
          meter inlet.

    Example: 
VPMact = 1.071 m\3\
pin = 101.7 kPa
Tstd = 293.15 K
pstd = 101.325 kPa
Tin = 340.5 K
[GRAPHIC] [TIFF OMITTED] TR25OC16.271

    (2) The following example provides a determination of 
Vmix based on CVS total flow and the removal of sample flow 
from one dilute exhaust gas analyzer and one PM sampling system that is 
utilizing secondary dilution. Note that your Vmix 
determination may vary from Eq. 1066.605-7 based on the number of flows 
that are removed from your dilute exhaust gas and whether your PM 
sampling system is using secondary dilution. For this example, 
Vmix is governed by the following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.272

Where:

VCVSstd = total dilute exhaust volume over the test interval 
          at the flow meter, corrected to standard reference conditions.
Vgasstd = total volume of sample flow through the gaseous 
          emission bench over the test interval, corrected to standard 
          reference conditions.
VPMstd = total volume of dilute exhaust sampled through the 
          filter over the test interval, corrected to standard reference 
          conditions.
Vsdastd = total volume of secondary dilution air flow sampled 
          through the filter over the test interval, corrected to 
          standard reference conditions.

    Example: 
    Using Eq. 1066.605-8:
VCVSstd = 170.451 m\3\, where VCVSact = 170.721 
          m\3\, pin = 101.7 kPa, and Tin = 294.7 K
    Using Eq. 1066.605-8:
Vgasstd = 0.028 m\3\, where Vgasact = 0.033 m\3\, 
          pin = 101.7 kPa, and Tin = 340.5 K
    Using Eq. 1066.605-8:
VPMstd = 0.925 m\3\, where VPMact = 1.071 m\3\, 
          pin = 101.7 kPa, and Tin = 340.5 K
    Using Eq. 1066.605-8:
Vsdastd = 0.527 m\3\, where Vsdaact = 0.531 m\3\, 
          pin = 101.7 kPa, and Tin = 296.3 K
Vmix = 170.451 + 0.028 + 0.925 - 0.527 = 170.878 m\3\

    (h) Calculate total flow volume over a test interval, 
V[flow], for a CVS or exhaust gas sampler as follows:
    (1) Varying versus constant flow rates. The calculation methods 
depend on differentiating varying and constant flow, as follows:
    (i) We consider the following to be examples of varying flows that 
require a continuous multiplication of concentration times flow rate: 
raw exhaust, exhaust diluted with a constant flow rate of dilution air, 
and CVS dilution with a CVS flow meter that does not have an upstream 
heat exchanger or electronic flow control.
    (ii) We consider the following to be examples of constant exhaust 
flows: CVS diluted exhaust with a CVS flow

[[Page 388]]

meter that has an upstream heat exchanger, an electronic flow control, 
or both.
    (2) Continuous sampling. For continuous sampling, you must 
frequently record a continuously updated flow signal. This recording 
requirement applies for both varying and constant flow rates.
    (i) Varying flow rate. If you continuously sample from a varying 
exhaust flow rate, calculate V[flow] using the following 
equation:
[GRAPHIC] [TIFF OMITTED] TR29JN21.270

Where:

[Delta]t = 1/[fnof]record

    Eq. 1066.605-11
    Example: 
N = 505
QCVS1= 0.276 m\3\/s
QCVS2= 0.294 m\3\/s
[fnof]record = 1 Hz

    Using Eq. 1066.605-11:

[Delta]t = 1/1 = 1 s
VCVS = (0.276 + 0.294 + QCVS505) [middot] 1
VCVS = 170.721 m\3\

    (ii) Constant flow rate. If you continuously sample from a constant 
exhaust flow rate, use the same calculation described in paragraph 
(h)(2)(i) of this section or calculate the mean flow recorded over the 
test interval and treat the mean as a batch sample, as described in 
paragraph (h)(3)(ii) of this section.
    (3) Batch sampling. For batch sampling, calculate total flow by 
integrating a varying flow rate or by determining the mean of a constant 
flow rate, as follows:
    (i) Varying flow rate. If you proportionally collect a batch sample 
from a varying exhaust flow rate, integrate the flow rate over the test 
interval to determine the total flow from which you extracted the 
proportional sample, as described in paragraph (h)(2)(i) of this 
section.
    (ii) Constant flow rate. If you batch sample from a constant exhaust 
flow rate, extract a sample at a proportional or constant flow rate and 
calculate V[flow] from the flow from which you extract the 
sample by multiplying the mean flow rate by the time of the test 
interval using the following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.274

    Example: 

QiCVS = 0.338 m\3\/s
[Delta]t = 505 s
VCVS = 0.338[middot]505
VCVS = 170.69 m\3\

[79 FR 23823, Apr. 28, 2014, as amended at 80 FR 9121, Feb. 19, 2015; 81 
FR 74203, Oct. 25, 2016; 86 FR 34583, June 29, 2021]



Sec.  1066.610  Dilution air background correction.

    (a) Correct the emissions in a gaseous sample for background using 
the following equation:

[[Page 389]]

[GRAPHIC] [TIFF OMITTED] TR28AP14.099

Where:
x[emission]dexh = measured emission concentration in dilute 
          exhaust (after dry-to-wet correction, if applicable).
x[emission]bkgnd = measured emission concentration in the 
          dilution air (after dry-to-wet correction, if applicable).
DF = dilution factor, as determined in paragraph (b) of this section.
[GRAPHIC] [TIFF OMITTED] TR28AP14.100

Where:

xCO2 = amount of CO2 measured in the sample over 
          the test interval.
xNMHC = amount of C1-equivalent NMHC measured in 
          the sample over the test interval.
xCH4 = amount of CH4 measured in the sample over 
          the test interval.

[[Page 390]]

xCO = amount of CO measured in the sample over the test 
          interval.
a = atomic hydrogen-to-carbon ratio of the test fuel. You may measure a 
          or use default values from Table 1 of 40 CFR 1065.655.
b = atomic oxygen-to-carbon ratio of the test fuel. You may measure b or 
          use default values from Table 1 of 40 CFR 1065.655.
          [GRAPHIC] [TIFF OMITTED] TR28AP14.101
          
    (c) Determine the dilution factor, DF, over the test interval for 
partial-flow dilution sample systems using the following equation:
[GRAPHIC] [TIFF OMITTED] TR28AP14.152

Where:

    Vdexhstd = total dilute exhaust volume sampled over the 
test interval, corrected to standard reference conditions.
    Vexhstd = total exhaust volume sampled from the vehicle, 
corrected to standard reference conditions.

[[Page 391]]

[GRAPHIC] [TIFF OMITTED] TR28AP14.102

    (d) Determine the time-weighted dilution factor, DFw, 
over the duty cycle using the following equation:
[GRAPHIC] [TIFF OMITTED] TR29JN21.272

Where:

N = number of test intervals
i = test interval number
t = duration of the test interval
DF = dilution factor over the test interval
    Example: 
N = 3
DF1 = 14.40
t1 = 505 s
DF2 = 24.48
t2 = 867 s
DF3 = 17.28
t3 = 505 s
[GRAPHIC] [TIFF OMITTED] TR29JN21.273


[79 FR 23823, Apr. 28, 2014, as amended at 86 FR 34583, June 29, 2021]



Sec.  1066.615  NOX intake-air humidity correction.

    You may correct NOX emissions for intake-air humidity as 
described in this section if the standard-setting part allows it. See 
Sec.  1066.605(c) for the proper sequence for applying the 
NOX intake-air humidity correction.
    (a) For vehicles at or below 14,000 pounds GVWR, apply a correction 
for vehicles with reciprocating engines operating over specific test 
cycles as follows:
    (1) Calculate a humidity correction using a time-weighted mean value 
for ambient humidity over the test interval. Calculate absolute ambient 
humidity, H, using the following equation:

[[Page 392]]

[GRAPHIC] [TIFF OMITTED] TR25OC16.275

Where:

MH2O = molar mass of H2O.
pd = saturated vapor pressure at the ambient dry bulb 
          temperature.
RH = relative humidity of ambient air
Mair = molar mass of air.
patmos = atmospheric pressure.

    Example: 
MH2O = 18.01528 g/mol
pd = 2.93 kPa
RH = 37.5% = 0.375
Mair = 28.96559 g/mol
patmos = 96.71 kPa
[GRAPHIC] [TIFF OMITTED] TR25OC16.266

    (2) Use the following equation to correct measured concentrations to 
a reference condition of 10.71 grams H2O vapor per kilogram 
of dry air for the FTP, US06, LA-92, SC03, and HFET test cycles:
[GRAPHIC] [TIFF OMITTED] TR19FE15.029

Where:

[chi]NOx = measured NOX emission concentration in 
          the sample, after dry-to-wet and background corrections.
Hs = humidity scale. Set = 1 for FTP, US06, LA-92, and HFET 
          test cycles. Set = 0.8825 for the SC03 test cycle.
H = ambient humidity, as determined in paragraph (a)(1) of this section.

    Example: 
H = 7.14741 g H2O vapor/kg dry air time weighted over the FTP 
          test cycle
[chi]NOx = 1.21 ppm
[GRAPHIC] [TIFF OMITTED] TR19FE15.030


[[Page 393]]


    (b) For vehicles above 14,000 pounds GVWR, apply correction factors 
as described in 40 CFR 1065.670.

[80 FR 9121, Feb. 19, 2015, as amended at 81 FR 74207, Oct. 25, 2016]



Sec.  1066.620  Removed water correction.

    Correct for removed water if water removal occurs upstream of a 
concentration measurement and downstream of a flow meter used to 
determine mass emissions over a test interval. Perform this correction 
based on the amount of water at the concentration measurement and on the 
amount of water at the flow meter.



Sec.  1066.625  Flow meter calibration calculations.

    This section describes the calculations for calibrating various flow 
meters based on mass flow rates. Calibrate your flow meter according to 
40 CFR 1065.640 instead if you calculate emissions based on molar flow 
rates.
    (a) PDP calibration. Perform the following steps to calibrate a PDP 
flow meter:
    (1) Calculate PDP volume pumped per revolution, Vrev, for 
each restrictor position from the mean values determined in Sec.  
1066.140:
[GRAPHIC] [TIFF OMITTED] TR25OC16.277

Where:

Viref = mean flow rate of the reference flow meter.
Tin = mean temperature at the PDP inlet.
pstd = standard pressure = 101.325 kPa.
fnPDP = mean PDP speed.
Pin = mean static absolute pressure at the PDP inlet.
Tstd = standard temperature = 293.15 K.

    Example: 
Viref = 0.1651 m\3\/s
Tin = 299.5 K
pstd = 101.325 kPa
fnPDP = 1205.1 r/min = 20.085 r/s
Pin = 98.290 kPa
Tstd = 293.15 K
[GRAPHIC] [TIFF OMITTED] TR25OC16.278

Vrev = 0.00866 m\3\/r
    (2) Calculate a PDP slip correction factor, Ks for each 
restrictor position from the mean values determined in Sec.  1066.140:
[GRAPHIC] [TIFF OMITTED] TR28AP14.110

Where:

fmPDP = mean PDP speed.
pout = mean static absolute pressure at the PDP outlet.

[[Page 394]]

pin = mean static absolute pressure at the PDP inlet.
[GRAPHIC] [TIFF OMITTED] TR28AP14.111

    (3) Perform a least-squares regression of Vrev, versus 
Ks, by calculating slope, a1, and intercept, 
a0, as described in 40 CFR 1065.602.
    (4) Repeat the procedure in paragraphs (a)(1) through (3) of this 
section for every speed that you run your PDP.
    (5) The following example illustrates a range of typical values for 
different PDP speeds:

       Table 1 of Sec.   1066.625--Example of PDP Calibration Data
------------------------------------------------------------------------
                                                             a0 (m\3\/
          fnPDP (revolution/s)              a1 (m\3\/s)     revolution)
------------------------------------------------------------------------
12.6....................................           0.841           0.056
16.5....................................           0.831          -0.013
20.9....................................           0.809           0.028
23.4....................................           0.788          -0.061
------------------------------------------------------------------------

    (6) For each speed at which you operate the PDP, use the appropriate 
regression equation from this paragraph (a) to calculate flow rate 
during emission testing as described in Sec.  1066.630.
    (b) SSV calibration. The equations governing SSV flow assume one-
dimensional isentropic inviscid flow of an ideal gas. Paragraph 
(b)(2)(iv) of this section describes other assumptions that may apply. 
If good engineering judgment dictates that you account for gas 
compressibility, you may either use an appropriate equation of state to 
determine values of Z as a function of measured pressure and 
temperature, or you may develop your own calibration equations based on 
good engineering judgment. Note that the equation for the flow 
coefficient, Cf, is based on the ideal gas assumption that 
the isentropic exponent, g, is equal to the ratio of specific heats, 
Cp/Cv. If good engineering judgment dictates using 
a real gas isentropic exponent, you may either use an appropriate 
equation of state to determine values of [gamma] as a function of 
measured pressure and temperature, or you may develop your own 
calibration equations based on good engineering judgment.
    (1) Calculate volume flow rate at standard reference conditions, 
Vistd, as follows

[[Page 395]]

[GRAPHIC] [TIFF OMITTED] TR25OC16.279

Where:

Cd = discharge coefficient, as determined in paragraph 
          (b)(2)(i) of this section.
Cf = flow coefficient, as determined in paragraph (b)(2)(ii) 
          of this section.
At = cross-sectional area at the venturi throat.
R = molar gas constant.
pin = static absolute pressure at the venturi inlet.
Tstd = standard temperature.
pstd = standard pressure.
Z = compressibility factor.
Mmix = molar mass of gas mixture.
Tin = absolute temperature at the venturi inlet.

    (2) Perform the following steps to calibrate an SSV flow meter:
    (i) Using the data collected in Sec.  1066.140, calculate 
Cd for each flow rate using the following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.280

Where:

Viref = measured volume flow rate from the reference flow 
          meter.
    (ii) Use the following equation to calculate Cf for each 
flow rate:
[GRAPHIC] [TIFF OMITTED] TR28AP14.113

Where:

g = isentropic exponent. For an ideal gas, this is the ratio of specific 
          heats of the gas mixture, Cp/Cv.
r = pressure ratio, as determined in paragraph (b)(2)(iii) of this 
          section.
b = ratio of venturi throat diameter to inlet diameter.

    (iii) Calculate r using the following equation:

[[Page 396]]

[GRAPHIC] [TIFF OMITTED] TR28AP14.114

Where:

[Delta]p = differential static pressure, calculated as venturi inlet 
          pressure minus venturi throat pressure.

    (iv) You may apply any of the following simplifying assumptions or 
develop other values as appropriate for your test configuration, 
consistent with good engineering judgment:
    (A) For raw exhaust, diluted exhaust, and dilution air, you may 
assume that the gas mixture behaves as an ideal gas (Z = 1).
    (B) For raw exhaust, you may assume g = 1.385.
    (C) For diluted exhaust and dilution air, you may assume g = 1.399.
    (D) For diluted exhaust and dilution air, you may assume the molar 
mass of the mixture, Mmix, is a function only of the amount 
of water in the dilution air or calibration air, as follows:
[GRAPHIC] [TIFF OMITTED] TR25OC16.281

Where:

Mair = molar mass of dry air.xH2O = amount of 
          H2O in the dilution air or calibration air, 
          determined as described in 40 CFR 1065.645.
MH2O = molar mass of water.

    Example: 
Mair = 28.96559 g/mol
xH2O = 0.0169 mol/mol
MH2O = 18.01528 g/mol
Mmix = 28.96559 [middot] (1 - 0.0169) + 18.01528 [middot] 
          0.0169 Mmix = 28.7805 g/mol
    (E) For diluted exhaust and dilution air, you may assume a constant 
molar mass of the mixture, Mmix, for all calibration and all 
testing if you control the amount of water in dilution air and in 
calibration air, as illustrated in the following table:

  Table 2 of Sec.   1066.625--Examples of Dilution Air and Calibration Air Dewpoints at Which You May Assume a
                                                  Constant Mmix
----------------------------------------------------------------------------------------------------------------
                                                                                     for the following ranges of
       If calibration Tdew ( [deg]C) is . . .             assume the following          Tdew ( [deg]C) during
                                                       constant Mmix (g/mol) . . .       emission tests \a\
----------------------------------------------------------------------------------------------------------------
<=0.................................................                      28.96559                          <=18
0...................................................                      28.89263                          <=21
5...................................................                      28.86148                          <=22
10..................................................                      28.81911                          <=24
15..................................................                      28.76224                          <=26
20..................................................                      28.68685                      -8 to 28
25..................................................                      28.58806                      12 to 31
30..................................................                      28.46005                      23 to 34
----------------------------------------------------------------------------------------------------------------
\a\ The specified ranges are valid for all calibration and emission testing over the atmospheric pressure range
  (80.000 to 103.325) kPa.

    (v) The following example illustrates the use of the governing 
equations to calculate Cd of an SSV flow meter at one 
reference flow meter value:

Viref = 2.395 m\3\/s
Z = 1
Mmix = 28.7805 g/mol = 0.0287805 kg/mol

[[Page 397]]

R = 8.314472 J/(mol[middot]K) = 8.314472 (m\2\[middot]kg)/
(s\2\[middot]mol[middot]K)
Tin = 298.15 K
At = 0.01824 m\2\
pin = 99.132 kPa = 99132 Pa = 99132 kg/(m[middot]s\2\)
g = 1.399
b = 0.8
[Delta]p = 7.653 kPa
[GRAPHIC] [TIFF OMITTED] TR25OC16.282

Cf = 0.472
[GRAPHIC] [TIFF OMITTED] TR25OC16.283

Cd = 0.985

    (vi) Calculate the Reynolds number, Re#, for each 
reference flow rate at standard conditions, Virefstd, using 
the throat diameter of the venturi, dt, and the air density 
at standard conditions, rstd. Because the dynamic viscosity, 
m, is needed to compute Re#, you may use your own fluid 
viscosity model to determine m for your calibration gas (usually air), 
using good engineering judgment. Alternatively, you may use the 
Sutherland three-coefficient viscosity model to approximate m, as shown 
in the following sample calculation for Re#:
[GRAPHIC] [TIFF OMITTED] TR25OC16.284

    Where, using the Sutherland three-coefficient viscosity model:

[[Page 398]]

[GRAPHIC] [TIFF OMITTED] TR25OC16.285

Where:

m0 = Sutherland reference viscosity.
T0 = Sutherland reference temperature.
S = Sutherland constant.

                                   Table 3 of Sec.   1066.625--Sutherland Three-Coefficient Viscosity Model Parameters
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                              m0                     T0                     S            Temperature range within    Pressure limit \2\
                                   --------------------------------------------------------------------- 2% ----------------------
              Gas \1\                                                                                            error \2\
                                       kg/(m[middot]s)               K                      K           --------------------------          kPa
                                                                                                                     K
--------------------------------------------------------------------------------------------------------------------------------------------------------
Air...............................  1.716[middot]10-5....  273..................  111..................  170 to 1900.............  <=1800.
CO2...............................  1.370[middot]10-5....  273..................  222..................  190 to 1700.............  <=3600.
H2O...............................  1.12[middot]10-5.....  350..................  1064.................  360 to 1500.............  <=10000.
O2................................  1.919[middot]10-5....  273..................  139..................  190 to 2000.............  <=2500.
N2................................  1.663[middot]10-5....  273..................  107..................  100 to 1500.............  <=1600.
--------------------------------------------------------------------------------------------------------------------------------------------------------
\1\ Use tabulated parameters only for the pure gases, as listed. Do not combine parameters in calculations to calculate viscosities of gas mixtures.
\2\ The model results are valid only for ambient conditions in the specified ranges.

    Example: 
m0 = 1.716[middot]10-5 kg/(m[middot]s)
T0 = 273 K
S = 111 K
[GRAPHIC] [TIFF OMITTED] TR25OC16.286

Tin = 298.15 K
dt = 152.4 mm = 0.1524 m
rstd = 1.1509 kg/m\3\
[GRAPHIC] [TIFF OMITTED] TR25OC16.287

Re# = 1.3027[middot]10\6\
    (vii) Calculate r using the following equation:
    [GRAPHIC] [TIFF OMITTED] TR25OC16.288
    

[[Page 399]]


    Example: 
    [GRAPHIC] [TIFF OMITTED] TR25OC16.289
    
[rho]std = 1.1964 kg/m \3\
    (viii) Create an equation for Cd as a function of 
Re#, using paired values of the two quantities. The equation 
may involve any mathematical expression, including a polynomial or a 
power series. The following equation is an example of a commonly used 
mathematical expression for relating Cd and Re#:
[GRAPHIC] [TIFF OMITTED] TR28AP14.118

    (ix) Perform a least-squares regression analysis to determine the 
best-fit coefficients for the equation and calculate SEE as described in 
40 CFR 1065.602.
    (x) If the equation meets the criterion of SEE <=0.5% [sdot] 
Cdmax, you may use the equation for the corresponding range 
of Re#, as described in Sec.  1066.630(b).
    (xi) If the equation does not meet the specified statistical 
criteria, you may use good engineering judgment to omit calibration data 
points; however, you must use at least seven calibration data points to 
demonstrate that you meet the criterion. For example, this may involve 
narrowing the range of flow rates for a better curve fit.
    (xii) Take corrective action if the equation does not meet the 
specified statistical criterion even after omitting calibration data 
points. For example, select another mathematical expression for the 
Cd versus Re# equation, check for leaks, or repeat 
the calibration process. If you must repeat the calibration process, we 
recommend applying tighter tolerances to measurements and allowing more 
time for flows to stabilize.
    (xiii) Once you have an equation that meets the specified 
statistical criterion, you may use the equation only for the 
corresponding range of Re#.
    (c) CFV calibration. Some CFV flow meters consist of a single 
venturi and some consist of multiple venturis where different 
combinations of venturis are used to meter different flow rates. For CFV 
flow meters that consist of multiple venturis, either calibrate each 
venturi independently to determine a separate calibration coefficient, 
Kv, for each venturi, or calibrate each combination of 
venturis as one venturi by determining Kv for the system.
    (1) To determine Kv for a single venturi or a combination 
of venturis, perform the following steps:
    (i) Calculate an individual Kv for each calibration set 
point for each restrictor position using the following equation:

[[Page 400]]

[GRAPHIC] [TIFF OMITTED] TR25OC16.290

Where:

Virefstd= mean flow rate from the reference flow meter, 
          corrected to standard reference conditions.
Tin= mean temperature at the venturi inlet.
Pin= mean static absolute pressure at the venturi inlet.

    (ii) Calculate the mean and standard deviation of all the 
Kv values (see 40 CFR 1065.602). Verify choked flow by 
plotting Kv as a function of pin. Kv 
will have a relatively constant value for choked flow; as vacuum 
pressure increases, the venturi will become unchoked and Kv 
will decrease. Paragraphs (c)(1)(iii) through (viii) of this section 
describe how to verify your range of choked flow.
    (iii) If the standard deviation of all the Kv values is 
less than or equal to 0.3% of the mean Kv, use the mean 
Kv in Eq. 1066.630-7, and use the CFV only up to the highest 
venturi pressure ratio, r, measured during calibration using the 
following equation:
[GRAPHIC] [TIFF OMITTED] TR25OC16.291

Where:

[Delta]pCFV = differential static pressure; venturi inlet 
          minus venturi outlet.
pin = mean static absolute pressure at the venturi inlet.

    (iv) If the standard deviation of all the Kv values 
exceeds 0.3% of the mean Kv, omit the Kv value 
corresponding to the data point collected at the highest r measured 
during calibration.
    (v) If the number of remaining data points is less than seven, take 
corrective action by checking your calibration data or repeating the 
calibration process. If you repeat the calibration process, we recommend 
checking for leaks, applying tighter tolerances to measurements and 
allowing more time for flows to stabilize.
    (vi) If the number of remaining Kv values is seven or 
greater, recalculate the mean and standard deviation of the remaining 
Kv values.
    (vii) If the standard deviation of the remaining Kv 
values is less than or equal to 0.3% of the mean of the remaining 
Kv, use that mean Kv in Eq 1066.630-7, and use the 
CFV values only up to the highest r associated with the remaining 
Kv.
    (viii) If the standard deviation of the remaining Kv 
still exceeds 0.3% of the mean of the remaining Kv values, 
repeat the steps in paragraph (c)(1)(iv) through (vii) of this section.
    (2) During exhaust emission tests, monitor sonic flow in the CFV by 
monitoring r. Based on the calibration data selected to meet the 
standard deviation criterion in paragraphs (c)(1)(iv) and (vii) of this 
section, in which Kv is constant, select the data values 
associated with the calibration point with the lowest absolute venturi 
inlet pressure to determine the r limit. Calculate r during the exhaust 
emission test using Eq. 1066.625-8 to demonstrate that the value of r 
during all emission tests is

[[Page 401]]

less than or equal to the r limit derived from the CFV calibration data.

[79 FR 23823, Apr. 28, 2016, as amended at 81 FR 74208, Oct. 25, 2016]



Sec.  1066.630  PDP, SSV, and CFV flow rate calculations.

    This section describes the equations for calculating flow rates from 
various flow meters. After you calibrate a flow meter according to Sec.  
1066.625, use the calculations described in this section to calculate 
flow during an emission test. Calculate flow according to 40 CFR 
1065.642 instead if you calculate emissions based on molar flow rates.
    (a) PDP. (1) Based on the speed at which you operate the PDP for a 
test interval, select the corresponding slope, a1, and 
intercept, a0, as determined in Sec.  1066.625(a), to 
calculate PDP flow rate, v, as follows:
[GRAPHIC] [TIFF OMITTED] TR25OC16.292

Where:

fnPDP = pump speed.
Vrev = PDP volume pumped per revolution, as determined in 
          paragraph (a)(2) of this section.
Tstd = standard temperature = 293.15 K.
pin = static absolute pressure at the PDP inlet.
Tin = absolute temperature at the PDP inlet.
pstd = standard pressure = 101.325 kPa.
    (2) Calculate Vrev using the following equation:
    [GRAPHIC] [TIFF OMITTED] TR25OC16.293
    
    pout = static absolute pressure at the PDP outlet.

    Example: 
a1 = 0.8405 m \3\/s
fnPDP = 12.58 r/s
pout = 99.950 kPa
pin = 98.575 kPa
a0 = 0.056 m \3\/r
Tin = 323.5 K
[GRAPHIC] [TIFF OMITTED] TR25OC16.294

Vrev = 0.063 m\3\/r
[GRAPHIC] [TIFF OMITTED] TR25OC16.295


[[Page 402]]


v= 0.7079 m\3\/s
    (b) SSV. Calculate SSV flow rate, v, as follows:
    [GRAPHIC] [TIFF OMITTED] TR25OC16.296
    
Where:

Cd = discharge coefficient, as determined based on the 
          Cd versus Re# equation in Sec.  
          1066.625(b)(2)(viii).
Cf = flow coefficient, as determined in Sec.  
          1066.625(b)(2)(ii).
At = venturi throat cross-sectional area.
R = molar gas constant.
pin = static absolute pressure at the venturi inlet.
Tstd = standard temperature.
pstd = standard pressure.
Z = compressibility factor.
Mmix = molar mass of gas mixture.
Tin = absolute temperature at the venturi inlet.
    Example: 
Cd = 0.890
Cf = 0.472
At = 0.01824 m\2\
R = 8.314472 J/(mol[middot]K) = 8.314472 (m\2\[middot]kg)/
          (s\2\[middot]mol[middot]K)
pin = 98.496 kPa
Tstd = 293.15 K
pstd = 101.325 kPa
Z = 1
Mmix = 28.7789 g/mol = 0.0287789 kg/mol
Tin = 296.85 K
[GRAPHIC] [TIFF OMITTED] TR25OC16.297

V = 2.155 m\3\/s
    (c) CFV. If you use multiple venturis and you calibrated each 
venturi independently to determine a separate calibration coefficient, 
Kv, for each venturi, calculate the individual volume flow 
rates through each venturi and sum all their flow rates to determine CFV 
flow rate, V. If you use multiple venturis and you calibrated venturis 
in combination, calculate V using the Kv that was determined 
for that combination of venturis.
    (1) To calculate V through one venturi or a combination of venturis, 
use the mean Kv you determined in Sec.  1066.625(c) and 
calculate V as follows:
[GRAPHIC] [TIFF OMITTED] TR25OC16.298

Where:

Kv = flow meter calibration coefficient.
Tin = temperature at the venturi inlet.
pin = absolute static pressure at the venturi inlet.

    Example: 
Kv = 0.074954 m\3\[middot]K\0.5\/(kPa[middot]s)

[[Page 403]]

pin = 99.654 kPa
Tin = 353.15 K
[GRAPHIC] [TIFF OMITTED] TR25OC16.299

V= 0.39748 m\3\/s
    (2) [Reserved]

[81 FR 74211, Oct. 25, 2016]



Sec.  1066.635  NMOG determination.

    For vehicles subject to an NMOG standard, determine NMOG as 
described in paragraph (a) of this section. Except as specified in the 
standard-setting part, you may alternatively calculate NMOG results 
based on measured NMHC emissions as described in paragraphs (c) through 
(f) of this section.
    (a) Determine NMOG by independently measuring alcohols and carbonyls 
as described in 40 CFR 1065.805 and 1065.845. Use good engineering 
judgment to determine which alcohols and carbonyls you need to measure. 
This would typically require you to measure all alcohols and carbonyls 
that you expect to contribute 1% or more of total NMOG. Calculate the 
mass of NMOG in the exhaust, mNMOG, with the following 
equation, using density values specified in Sec.  1066.1005(f):
[GRAPHIC] [TIFF OMITTED] TR25OC16.300

Where:

mNMHC = the mass of NMHC and all oxygenated hydrocarbon (OHC) 
in the exhaust, as determined using Eq. 1066.605-2. Calculate NMHC mass 
based on [rho]NMHC.
rNMHC = the effective C1-equivalent density of 
NMHC as specified in Sec.  1066.1005(f).
mOHCi = the mass of oxygenated species i in the exhaust 
calculated using Eq. 1066.605-2.
rOCHi = the C1-equivalent density of oxygenated 
species i.
RFOHCi[THC-FID] = the response factor of a THC-FID to 
oxygenated species i relative to propane on a C1-equivalent 
basis as determined in 40 CFR 1065.845.

    (b) The following example shows how to determine NMOG as described 
in paragraph (a) of this section for (OHC) compounds including ethanol 
(C2H5OH), methanol (CH3OH), 
acetaldehyde (C2H4O), and formaldehyde 
(CH2O) as C1-equivalent concentrations:

mNMHC = 0.0125 g
mCH3OH = 0.0002 g
mC2H5OH = 0.0009 g
mCH2O = 0.0001 g
mC2H4O = 0.00005 g
RFCH3OH[THC-FID] = 0.63
RFC2H5OH[THC-FID] = 0.75
RFCH2O[THC-FID] = 0.00
RFC2H4O[THC-FID] = 0.50
rNMHC-liq = 576.816 g/m\3\
rCH3OH = 1332.02 g/m\3\
rC2H5OH = 957.559 g/m\3\
rCH2O = 1248.21 g/m\3\
rC2H4O = 915.658 g/m\3\

[[Page 404]]

[GRAPHIC] [TIFF OMITTED] TR28AP14.128

    (c) For gasoline containing less than 25% ethanol by volume, you may 
calculate NMOG from measured NMHC emissions as follows:
    (1) For hot-start and hot-running test cycles or intervals other 
than the FTP, you may determine NMOG based on the NMHC emission rate 
using the following equation:
[GRAPHIC] [TIFF OMITTED] TR28AP14.129

Where:

eNMOGh = mass emission rate of NMOG from the hot-running test 
          cycle.
eNMHCh = mass emission rate of NMHC from the hot-running test 
          cycle, calculated using rNMHC-liq.

    Example: 
eNMHCh = 0.025 g/mi
eNMOGh = 0.025 [middot] 1.03 = 0.026 g/mi

    (2) You may determine weighted composite NMOG for FTP testing based 
on the weighted composite NMHC emission rate and the volume percent of 
ethanol in the fuel using the following equation:
[GRAPHIC] [TIFF OMITTED] TR28AP14.130

Where:

eNMOGcomp = weighted FTP composite mass emission rate of 
          NMOG.
eNMHCcomp = weighted FTP composite mass emission rate of 
          NMHC, calculated using rNMHC-liq.
VPEtOH = volume percentage of ethanol in the test fuel. Use 
          good engineering judgment to determine this value either as 
          specified in 40 CFR 1065.710 or based on blending volumes, 
          taking into account any denaturant.

    Example: 
eNMHCcomp = 0.025 g/mi
VPEtOH = 10.1%
eNMOGcomp = 0.025 [middot] (1.0302 + 0.0071 [middot] 10.1) = 
          0.0275 g/mi

    (3) You may determine NMOG for the transient portion of the FTP 
cold-start test for use in fuel economy and CREE calculations based on 
the NMHC emission rate for the test interval and the volume percent of 
ethanol in the fuel using the following equation:

[[Page 405]]

[GRAPHIC] [TIFF OMITTED] TR28AP14.131

Where:

eNMOG-FTPct = mass emission rate of NMOG from the transient 
          portion of the FTP cold-start test (generally known as bag 1).
eNMHC-FTPct = mass emission rate of NMHC from the transient 
          portion of the FTP cold-start test (bag 1), calculated using 
          rNMHC-liq.

    Example: 
eNMHC-FTPct = 0.052 g/mi
VPEtOH = 10.1%
eNMOG-FTPct = 0.052 [middot] (1.0246 + 0.0079 [middot] 10.1) 
          = 0.0574 g/mi

    (4) You may determine NMOG for the stabilized portion of the FTP 
test for either the cold-start test or the hot-start test (bag 2 or bag 
4) for use in fuel economy and CREE calculations based on the 
corresponding NMHC emission rate and the volume percent of ethanol in 
the fuel using the following equation:
[GRAPHIC] [TIFF OMITTED] TR28AP14.132

Where:

eNMOG-FTPcs-hs = mass emission rate of NMOG from the 
          stabilized portion of the FTP test (bag 2 or bag 4).
eNMHC-FTPcs-hs = mass emission rate of NMHC from the 
          stabilized portion of the FTP test (bag 2 or bag 4), 
          calculated using rNMHC-liq.

    (5) You may determine NMOG for the transient portion of the FTP hot-
start test for use in fuel economy and CREE calculations based on the 
NMHC emission rate for the test interval and the volume percent of 
ethanol in the fuel using the following equation:
[GRAPHIC] [TIFF OMITTED] TR28AP14.133

Where:

eNMOG-FTPht = mass emission rate of NMOG from the transient 
          portion of the FTP hot-start test (bag 3).
eNMHC-FTPht = mass emission rate of NMHC from the transient 
          portion of the FTP hot-start test (bag 3), calculated using 
          rNMHC-liq.

    (6) For PHEVs, you may determine NMOG based on testing over one full 
UDDS using Eq. 1066.635-3.
    (d) You may take the following alternative steps when determining 
fuel economy and CREE under 40 CFR part 600 for testing with ethanol-
gasoline blends that have up to 25% ethanol by volume:
    (1) Calculate NMOG by test interval using Eq. 1066.635-3 for 
individual bag measurements from the FTP.
    (2) For HEVs, calculate NMOG for two-bag FTPs using Eq. 1066.635-3 
as described in 40 CFR 600.114.
    (e) We consider NMOG values for diesel-fueled vehicles, CNG-fueled 
vehicles, LNG-fueled vehicles, and LPG-fueled vehicles to be equivalent 
to

[[Page 406]]

NMHC emission values for all test cycles.
    (f) For all fuels not covered by paragraphs (c) and (e) of this 
section, manufacturers may propose a methodology to calculate NMOG 
results from measured NMHC emissions. We will approve adjustments based 
on comparative testing that demonstrates how to properly represent NMOG 
based on measured NMHC emissions.

[79 FR 23823, Apr. 28, 2014, as amended at 80 FR 9122, Feb. 19, 2015; 81 
FR 74212, Oct. 25, 2016]



Sec.  1066.695  Data requirements.

    Record information for each test as follows:
    (a) Test number.
    (b) A brief description of the test vehicle (or other system/device 
tested).
    (c) Date and time of day for each part of the test sequence.
    (d) Test results. Also include a validation of driver accuracy as 
described in Sec.  1066.425(j).
    (e) Driver and equipment operators.
    (f) Vehicle information as applicable, including identification 
number, model year, applicable emission standards (including bin 
standards or family emission limits, as applicable), vehicle model, 
vehicle class, test group, durability group, engine family, evaporative/
refueling emission family, basic engine description (including 
displacement, number of cylinders, turbocharger/supercharger used, and 
catalyst type), fuel system (type of fuel injection and fuel tank 
capacity and location), engine code, GVWR, applicable test weight, 
inertia weight class, actual curb weight at zero miles, actual road load 
at 50 mi/hr, transmission class and configuration, axle ratio, odometer 
reading, idle rpm, and measured drive wheel tire pressure.
    (g) Dynamometer identification, inertia weight setting, indicated 
power absorption setting, and records to verify compliance with the 
driving distance and cycle-validation criteria as calculated from 
measured roll or shaft revolutions.
    (h) Analyzer bench identification, analyzer ranges, recordings of 
analyzer output during zero, span, and sample readings.
    (i) Associate the following information with the test record: test 
number, date, vehicle identification, vehicle and equipment operators, 
and identification of the measurements recorded.
    (j) Test cell barometric pressure and humidity. You may use a 
central laboratory barometer if the barometric pressure in each test 
cell is shown to be within 0.1% of the barometric 
pressure at the central barometer location.
    (k) Records to verify compliance with the ambient temperature 
requirements throughout the test procedure and records of fuel 
temperatures during the running loss test.
    (l) [Reserved]
    (m) For CVS systems, record dilution factor for each test interval 
and the following additional information:
    (1) For CFV and SSV testing, Vmix for each interval of 
the exhaust test.
    (2) For PDP testing, test measurements required to calculate 
Vmix for each test interval.
    (n) The humidity of the dilution air, if you remove H2O 
from an emission sample before measurement.
    (o) Temperature of the dilute exhaust mixture and secondary dilution 
air (in the case of a double-dilution system) at the inlet to the 
respective gas meter or flow instrumentation used for PM sampling. 
Determine minimum values, maximum values, mean values, and percent of 
time outside of the tolerance over each test interval.
    (p) The maximum exhaust gas temperature over the course of the test 
interval within 20 cm upstream or downstream of PM sample media.
    (q) If applicable, the temperatures of the heated FID, the gas in 
the heated sample line, and the heated filter. Determine minimum values, 
maximum values, average values, and percent of time outside of the 
tolerance over each test interval.
    (r) Gas meter or flow measurement instrumentation readings used for 
batch sampling over each test interval. Determine minimum, maximum, and 
average values over each test interval.
    (s) The stabilized pre-test weight and post-test weight of each 
particulate sample media (e.g., filter).
    (t) Continuous temperature and humidity of the ambient air in which 
the

[[Page 407]]

PM sample media are stabilized. Determine minimum values, maximum 
values, average values, and percent of time outside of the tolerance 
over each test interval.
    (u) For vehicles fueled by natural gas, the test fuel composition, 
including all carbon-containing compounds (including CO2, but 
excluding CO). Record C1 and C2 compounds 
individually. You may record C3 through C5 
hydrocarbons together, and you may record C6 and heavier 
hydrocarbon compounds together.
    (v) For vehicles fueled by liquefied petroleum gas, the test fuel 
composition, including all carbon-containing compounds (including 
CO2, but excluding CO). Record C1 through 
C4 compounds individually. You may record C5 and 
heavier hydrocarbons together.
    (w) For the AC17 test in Sec.  1066.845, interior volume, climate 
control system type and characteristics, refrigerant used, compressor 
type, and evaporator/condenser characteristics.
    (x) Additional information related to evaporative emissions. 
[Reserved]
    (y) Additional information related to refueling emissions. 
[Reserved]

[[79 FR 23823, Apr. 28, 2016, as amended at 81 FR 74213, Oct. 25, 2016]



               Subpart H_Cold Temperature Test Procedures



Sec.  1066.701  Applicability and general provisions.

    (a) The procedures of this part 1066 may be used for testing at any 
ambient temperature. Section 1066.710 describes the provisions that 
apply for testing vehicles at a nominal temperature of -7 [deg]C (20 
[deg]F); these procedures apply for motor vehicles as described in 40 
CFR part 86, subpart S, and 40 CFR part 600. For other vehicles, see the 
standard-setting part to determine if your vehicle is required to meet 
emission standards outside the normal (20 to 30) [deg]C ((68 to 86) 
[deg]F) temperature range.
    (b) Do not apply the humidity correction factor in Sec.  1066.615(a) 
for cold temperature testing.

[79 FR 23823, Apr. 28, 2014, as amended at 80 FR 9122, Feb. 19, 2015]



Sec.  1066.710  Cold temperature testing procedures for measuring CO
and NMHC emissions and determining fuel economy.

    This section describes procedures for measuring carbon monoxide (CO) 
and nonmethane hydrocarbon (NMHC) emissions and determining fuel economy 
on a cold day using the FTP test cycle (see Sec.  1066.801).
    (a) Follow the exhaust emission measurement procedures specified in 
Sec. Sec.  1066.410 through 1066.425 and Sec.  1066.815(d), subject to 
the following exceptions and additional provisions:
    (1) Measure and control ambient conditions as specified in paragraph 
(b) of this section.
    (2) Use the vehicle's heater and defroster as specified in paragraph 
(c) of this section.
    (3) Precondition and stabilize the vehicle as specified in 
paragraphs (d) and (e) of this section. Ensure that there is no 
precipitation or dew on the vehicle before the emission test.
    (4) For dynamometers that have independently heated bearings, start 
the emission test within 20 minutes after warming up the dynamometer; 
for other types of dynamometers, start the emission test within 10 
minutes after warming up the dynamometer.
    (5) Adjust the dynamometer to simulate vehicle operation on the road 
at -7 [deg]C as described in Sec.  1066.305(b).
    (6) Analyze samples for NMHC, CO, and CO2. You do not 
need to analyze samples for other pollutants.
    (b) Maintain ambient conditions as follows instead of following the 
specifications in subpart E of this part:
    (1) Ambient temperature for emission tests. Measure and record 
ambient temperature in the test cell at least once every 60 seconds 
during the sampling period. The temperature must be (-7.0 1.7) [deg]C at the start of the test and average 
temperature must be (-7.0 2.8) [deg]C during the 
test. Instantaneous temperature values may be above -4.0 [deg]C or below 
-9.0 [deg]C, but not for more than 3 minutes at a time during the test. 
At no time may the ambient temperatures be below -12.0 [deg]C or above -
1.0 [deg]C.
    (2) Ambient temperature for preconditioning. Instantaneous ambient 
temperature values may be above -4.0 [deg]C or below -9.0 [deg]C but not 
for more than

[[Page 408]]

3 minutes at a time during the preconditioning period. At no time may 
the ambient temperatures be below -12.0 [deg]C or above -1.0 [deg]C. The 
average ambient temperature during preconditioning must be (-7.0 2.8) [deg]C. You may precondition vehicles at 
temperatures above -7.0 [deg]C or with a temperature tolerance greater 
than that described in this section (or both) if you determine that this 
will not cause NMHC, CO, or CO2 emissions to decrease; if you 
modify the temperature specifications for vehicle preconditioning, 
adjust the procedures described in this section appropriately for your 
testing.
    (3) Ambient humidity. Maintain humidity low enough to prevent 
condensation on the dynamometer rolls during testing.
    (c) During the test, operate the vehicle's interior climate control 
system with the heat on and air conditioning off. You may not use any 
supplemental auxiliary heat during this testing. You may set the heater 
to any temperature and fan setting during vehicle preconditioning.
    (1) Manual and automatic temperature control. Unless you rely on 
full automatic control as specified in paragraph (c)(2) of this section, 
take the following steps to control heater settings:
    (i) Set the climate control system as follows before the first 
acceleration (t = 20 s), or before starting the vehicle if the climate 
control system allows it:
    (A) Temperature. Set controls to maximum heat. For automatic 
temperature control systems that allow the operator to select a specific 
temperature, set the heater control to 72 [deg]F or higher.
    (B) Fan speed. Set the fan speed to full off or the lowest available 
speed if a full off position is not available.
    (C) Airflow direction. Direct airflow to the front window (window 
defrost mode).
    (D) Air source. If independently controllable, set the system to 
draw in outside air.
    (ii) At the second idle of the test cycle, which occurs 125 seconds 
after the start of the test, set the fan speed to maximum. Complete by 
130 seconds after the start of the test. Leave temperature and air 
source settings unchanged.
    (iii) At the sixth idle of the test interval, which occurs at the 
deceleration to zero miles per hour 505 seconds after the start of the 
test, set the fan speed to the lowest setting that maintains air flow. 
Complete these changes by 510 seconds after the start of the test. You 
may use different vent and fan speed settings for the remainder of the 
test. Leave the temperature and air source settings unchanged.
    (2) Full automatic control. Vehicles with full automatic control 
systems may instead operate as described in this paragraph (c)(2). Set 
the temperature to 72 [deg]F in full automatic control for the whole 
test, allowing the vehicle to adjust the air temperature and direction 
of the airflow.
    (3) Multiple-zone systems. For vehicles that have separate driver 
and passenger controls or separate front and rear controls, you must set 
all temperature and fan controls as described in paragraphs (c)(1) and 
(2) of this section, except that rear controls need not be set to 
defrost the front window.
    (4) Alternative test procedures. We may approve the use of other 
settings under 40 CFR 86.1840 if a vehicle's climate control system is 
not compatible with the provisions of this section.
    (d) Take the following steps to prepare and precondition vehicles 
for testing under this section:
    (1) Prepare the vehicle as described in Sec.  1066.810(a).
    (2) Fill the fuel tank to approximately 40% of the manufacturer's 
nominal fuel tank capacity with the appropriate test fuel for cold 
temperature testing as specified 40 CFR Part 1065, subpart H. The 
temperature of the dispensed test fuel must be at or below 15.5 [deg]C. 
If the leftover fuel in the fuel tank before the refueling event does 
not meet these specifications, drain the fuel tank before refueling. You 
may operate the vehicle prior to the preconditioning drive to eliminate 
fuel effects on adaptive memory systems.
    (3) You may start the preconditioning drive once the fuel in the 
fuel tank reaches (-12.6 to -1.4) [deg]C. Precondition the vehicle as 
follows:
    (i) Push or drive the vehicle onto the dynamometer.

[[Page 409]]

    (ii) Operate the vehicle over one UDDS. You may perform additional 
vehicle preconditioning with repeated driving over the UDDS, subject to 
our advance approval.
    (iii) Turn off the test vehicle and any cooling fans within 5 
minutes after completing the preconditioning drive. Ambient temperature 
must be between (-12.0 and -1.0) [deg]C in the 5 minutes following the 
preconditioning drive.
    (iv) Do not manually purge or load the evaporative canister.
    (e) Soak the vehicle for (12 to 36) hours to stabilize it at test 
temperatures before starting the emission test as described in this 
paragraph (e). If you move a stabilized vehicle through a warm area when 
transporting it to the dynamometer for testing, you must restabilize the 
vehicle by holding it at an ambient temperature within the range 
specified in paragraph (b)(1) of this section for at least six times as 
long as the vehicle was exposed to warmer temperatures. Use one of the 
following methods to reach a stabilized condition:
    (1) Cold storage. Measure and record ambient temperature in the test 
cell at least once every 60 seconds during the ambient cold soak period. 
These ambient temperatures may be above -4.0 [deg]C or below -9.0 
[deg]C, but not for more than 3 minutes at a time. Use measured values 
to calculate an hourly average temperature. Each hourly average 
temperature must be (-7.0 [deg]C 2.8) [deg]C.
    (2) Forced-cooling or warming. Position fans to blow temperature-
controlled air onto the vehicle to stabilize the vehicle at the 
specified temperatures for emission testing. Position fans to target the 
vehicle's drive train, engine block, and radiator rather than the oil 
pan. You may not place fans under the vehicle. You may consider the 
vehicle to be stabilized at the test temperature when the bulk oil 
temperature reaches (-8.7 to -5.3) [deg]C; measure oil temperature at 
one or more points away from the side or bottom surfaces of the oil pan. 
Each oil temperature measurement must be within the specified range 
before stabilization is complete. Once the vehicle reaches this 
stabilized condition, cold soak the vehicle within the stabilized 
temperature range for at least one hour before starting the emission 
test. During this time, keep the ambient temperature within the range 
specified in paragraph (b)(1) of this section.
    (f) The following figure illustrates the cold temperature testing 
sequence for measuring CO and NMHC emissions and determining fuel 
economy:

   Figure 1 to paragraph (f) Sec.  1066.710--Cold Temperature Testing 
   Sequence for Measuring CO and NMHC Emissions and Determining Fuel 
                                 Economy

[[Page 410]]

[GRAPHIC] [TIFF OMITTED] TR24JA23.161


[79 FR 23823, Apr. 28, 2014, as amended at 80 FR 9122, Feb. 19, 2015; 81 
FR 74213, Oct. 25, 2016; 86 FR 34583, June 29, 2021; 88 FR 4708, Jan. 
24, 2023]



      Subpart I_Exhaust Emission Test Procedures for Motor Vehicles



Sec.  1066.801  Applicability and general provisions.

    This subpart I specifies how to apply the test procedures of this 
part for light-duty vehicles, light-duty trucks, and heavy-duty vehicles 
at or below 14,000 pounds GVWR that are subject to chassis testing for 
exhaust emissions under 40 CFR Part 86, subpart S. For these vehicles, 
references in this part 1066 to the standard-setting part include this 
subpart I.
    (a) Use the procedures detailed in this subpart to measure vehicle 
emissions over a specified drive schedule in conjunction with subpart E 
of this part. Where the procedures of subpart E of this part differ from 
this subpart I, the provisions in this subpart I take precedence.
    (b) Collect samples of every pollutant for which an emission 
standard applies, unless specified otherwise.
    (c) This subpart covers the following test procedures:
    (1) The Federal Test Procedure (FTP), which includes the general 
driving cycle. This procedure is also used for measuring evaporative 
emissions. This may be called the conventional test since it was adopted 
with the earliest emission standards.

[[Page 411]]

    (i) The FTP consists of one Urban Dynamometer Driving Schedule 
(UDDS) as specified in paragraph (a) of Appendix I of 40 CFR Part 86, 
followed by a 10-minute soak with the engine off and repeat driving 
through the first 505 seconds of the UDDS. Note that the UDDS represents 
about 7.5 miles of driving in an urban area. Engine startup (with all 
accessories turned off), operation over the initial UDDS, and engine 
shutdown make a complete cold-start test. The hot-start test consists of 
the first 505 seconds of the UDDS following the 10-minute soak and a 
hot-running portion of the UDDS after the first 505 seconds. The first 
505 seconds of the UDDS is considered the transient portion; the 
remainder of the UDDS is considered the stabilized (or hot-stabilized) 
portion. The hot-stabilized portion for the hot-start test is generally 
measured during the cold-start test; however, in certain cases, the hot-
start test may involve a second full UDDS following the 10-minute soak, 
rather than repeating only the first 505 seconds. See Sec. Sec.  
1066.815 and 1066.820.
    (ii) Evaporative emission testing includes a preconditioning drive 
with the UDDS and a full FTP cycle, including exhaust measurement, 
followed by evaporative emission measurements. In the three-day diurnal 
test sequence, the exhaust test is followed by a running loss test 
consisting of a UDDS, then two New York City Cycles as specified in 
paragraph (e) of Appendix I of 40 CFR Part 86, followed by another UDDS; 
see 40 CFR 86.134. Note that the New York City Cycle represents about 
1.18 miles of driving in a city center. The running loss test is 
followed by a high-temperature hot soak test as described in 40 CFR 
86.138 and a three-day diurnal emission test as described in 40 CFR 
86.133. In the two-day diurnal test sequence, the exhaust test is 
followed by a low-temperature hot soak test as described in 40 CFR 
86.138-96(k) and a two-day diurnal emission test as described in 40 CFR 
86.133-96(p).
    (iii) Refueling emission tests for vehicles that rely on integrated 
control of diurnal and refueling emissions includes vehicle operation 
over the full FTP test cycle corresponding to the three-day diurnal test 
sequence to precondition and purge the evaporative canister. For non-
integrated systems, there is a preconditioning drive over the UDDS and a 
refueling event, followed by repeated UDDS driving to purge the 
evaporative canister. The refueling emission test procedures are 
described in 40 CFR 86.150 through 86.157.
    (2) The Supplemental Federal Test Procedure (SFTP) measures the 
emission effects from aggressive driving and operation with the 
vehicle's air conditioner. The SFTP is based on a composite of three 
different test elements. In addition to the FTP, vehicles generally 
operate over the US06 and SC03 driving schedules as specified in 
paragraphs (g) and (h) of Appendix I of 40 CFR part 86, respectively. In 
the case of heavy-duty vehicles above 10,000 pounds GVWR and at or below 
14,000 pounds GVWR, SFTP testing involves additional driving over the 
Hot LA-92 driving schedule as specified in paragraph (c) of 40 CFR part 
86, Appendix I, instead of the US06 driving schedule. Note that the US06 
driving schedule represents about 8.0 miles of relatively aggressive 
driving; the SC03 driving schedule represents about 3.6 miles of urban 
driving with the air conditioner operating; and the hot portion of the 
LA-92 driving schedule represents about 9.8 miles of relatively 
aggressive driving for commercial trucks. See Sec.  1066.830.
    (3) The Highway Fuel Economy Test (HFET) is specified in Appendix I 
of 40 CFR part 600. Note that the HFET represents about 10.2 miles of 
rural and freeway driving with an average speed of 48.6 mi/hr and a 
maximum speed of 60.0 mi/hr. See Sec.  1066.840.
    (4) Cold temperature standards apply for CO and NMHC emissions when 
vehicles operate over the FTP at a nominal temperature of -7 [deg]C. See 
40 CFR Part 86, subpart C, and subpart H of this part.
    (5) Emission measurement to determine air conditioning credits for 
greenhouse gas standards. In this optional procedure, manufacturers 
operate vehicles over repeat runs of the AC17 test sequence to allow for 
calculating credits as part of demonstrating compliance with 
CO2 emission standards. The AC17 test sequence consists of a 
UDDS

[[Page 412]]

preconditioning drive, followed by emission measurements over the SC03 
and HFET driving schedules. See Sec.  1066.845.
    (d) The following provisions apply for all testing:
    (1) Ambient temperatures encountered by the test vehicle must be (20 
to 30) [deg]C, unless otherwise specified. Where ambient temperature 
specifications apply before or between test measurements, the vehicle 
may be exposed to temperatures outside of the specified range for up to 
10 minutes to account for vehicle transport or other actions to prepare 
for testing. The temperatures monitored during testing must be 
representative of those experienced by the test vehicle. For example, do 
not measure ambient temperatures near a heat source.
    (2) Do not operate or store the vehicle at an incline if good 
engineering judgment indicates that it would affect emissions.
    (3) If a test is void after collecting emission data from previous 
test segments, the test may be repeated to collect only those data 
points needed to complete emission measurements. You may combine 
emission measurements from different test runs to demonstrate compliance 
with emission standards.
    (4) Prepare vehicles for testing as described in Sec.  1066.810.
    (e) The following figure illustrates the FTP test sequence for 
measuring exhaust and evaporative emissions:

[[Page 413]]

[GRAPHIC] [TIFF OMITTED] TR29JN21.274


[79 FR 23823, Apr. 28, 2014, as amended at 80 FR 9123, Feb. 19, 2015; 81 
FR 74213, Oct. 25, 2016; 86 FR 34583, June 29, 2021]



Sec.  1066.805  Road-load power, test weight, and inertia weight 
class determination.

    (a) Simulate a vehicle's test weight on the dynamometer using the 
appropriate equivalent test weight shown in Table 1 of this section. 
Equivalent test weights are established according to each vehicle's test 
weight basis, as described in paragraph (b) of this section. Table 1 
also specifies the inertia weight class corresponding to each equivalent 
test weight; the inertia weight class allows for grouping vehicles with 
a range of equivalent test weights. Table 1 follows:

[[Page 414]]



      Table 1 of Sec.   1066.805--Equivalent Test Weights (pounds)
------------------------------------------------------------------------
                                                 Equivalent    Inertia
                  Test weight                       test        weight
------------------------------------------------------------------------
Up to 1062....................................         1000         1000
1063 to 1187..................................         1125         1000
1188 to 1312..................................         1250         1250
1313 to 1437..................................         1375         1250
1438 to 1562..................................         1500         1500
1563 to 1687..................................         1625         1500
1688 to 1812..................................         1750         1750
1813 to 1937..................................         1875         1750
1938 to 2062..................................         2000         2000
2063 to 2187..................................         2125         2000
2188 to 2312..................................         2250         2250
2313 to 2437..................................         2375         2250
2438 to 2562..................................         2500         2500
2563 to 2687..................................         2625         2500
2688 to 2812..................................         2750         2750
2813 to 2937..................................         2875         2750
2938 to 3062..................................         3000         3000
3063 to 3187..................................         3125         3000
3188 to 3312..................................         3250         3000
3313 to 3437..................................         3375         3500
3438 to 3562..................................         3500         3500
3563 to 3687..................................         3625         3500
3688 to 3812..................................         3750         3500
3813 to 3937..................................         3875         4000
3938 to 4125..................................         4000         4000
4126 to 4375..................................         4250         4000
4376 to 4625..................................         4500         4500
4626 to 4875..................................         4750         4500
4876 to 5125..................................         5000         5000
5126 to 5375..................................         5250         5000
5376 to 5750..................................         5500         5500
5751 to 6250..................................         6000         6000
6251 to 6750..................................         6500         6500
6751 to 7250..................................         7000         7000
7251 to 7750..................................         7500         7500
7751 to 8250..................................         8000         8000
8251 to 8750..................................         8500         8500
8751 to 9250..................................         9000         9000
9251 to 9750..................................         9500         9500
9751 to 10250.................................        10000        10000
10251 to 10750................................        10500        10500
10751 to 11250................................        11000        11000
11251 to 11750................................        11500        11500
11751 to 12250................................        12000        12000
12251 to 12750................................        12500        12500
12751 to 13250................................        13000        13000
13251 to 13750................................        13500        13500
13751 to 14000................................        14000        14000
------------------------------------------------------------------------

    (b) The test weight basis for non-MDPV heavy-duty vehicles is 
``adjusted loaded vehicle weight''. For all other vehicles, the test 
weight basis for establishing equivalent test weight is ``loaded vehicle 
weight''. These load terms are defined in 40 CFR 86.1803.
    (c) For FTP, SFTP, New York City Cycle, HFET, and LA-92 testing, 
determine road-load forces for each test vehicle at speeds between 9.3 
and 71.5 miles per hour. The road-load force must represent vehicle 
operation on a smooth, level road with no wind or calm winds, no 
precipitation, an ambient temperature of approximately 20 [deg]C, and 
atmospheric pressure of 98.21 kPa. You may extrapolate road-load force 
for speeds below 9.3 mi/hr.

[79 FR 23823, Apr. 28, 2016, as amended at 81 FR 74213, Oct. 25, 2016]



Sec.  1066.810  Vehicle preparation.

    (a) Include additional fittings and adapters as required to 
accommodate a fuel drain at the lowest point possible in the tank(s) as 
installed on the vehicle.
    (b) For preconditioning that involves loading an evaporative 
emission canister with butane, provide valving or other means to allow 
for purging and loading the canister.
    (c) For vehicles to be tested for running loss emissions (40 CFR 
86.134), prepare the fuel tank for measuring temperature and pressure as 
specified in 40 CFR 86.107-98(e) and (f) and 40 CFR 86.134. Vapor 
temperature measurement is optional during the running loss test.
    (d) For vehicles to be tested for running loss emissions, prepare 
the exhaust system by sealing or plugging all detectable sources of 
exhaust gas leaks. Inspect or test the exhaust system to ensure that 
there are no leaks that would cause exhaust hydrocarbon emissions to be 
detected as running losses.
    (e) The following provisions apply for preconditioning steps to 
reduce nonfuel emissions to normal vehicle background levels for 
vehicles subject to Tier 3 evaporative emission standards under 40 CFR 
86.1813:
    (1) You must notify us in advance if you plan to perform such 
preconditioning. This notice must include a detailed description of the 
intended procedures and any measurements or thresholds for determining 
when stabilization is complete. You need not repeat this notification 
for additional vehicle testing in the same or later model years as long 
as your preconditioning practice conforms to these procedures.
    (2) You may precondition a vehicle as described in paragraph (e)(1) 
of this section only within 12 months after the vehicle's original date 
of manufacture, except that you may ask us to approve further 
preconditioning steps for any testing to address identifiable sources of 
nonfuel emissions beyond what

[[Page 415]]

would generally occur with an appropriately aged in-use vehicle. For 
example, you may clean up fluid leaks and you may perform further off-
vehicle preconditioning for tires or other replacement parts that are 
less than 12 months old. You may also replace the spare tire with an 
aged spare tire, and you may replace the windshield washer fluid with 
water.



Sec.  1066.815  Exhaust emission test procedures for FTP testing.

    (a) General. The FTP exhaust emission test sequence consists of a 
cold-start test and a hot-start test as described in Sec.  1066.801.
    (b) PM sampling options. Collect PM using any of the procedures 
specified in paragraphs (b)(1) through (5) of this section and use the 
corresponding equation in Sec.  1066.820 to calculate FTP composite 
emissions. Testing must meet the requirements related to filter face 
velocity as described in Sec.  1066.110(b)(2)(iii)(C), except as 
specified in paragraphs (b)(4) and (5) of this section. For procedures 
involving flow weighting, set the filter face velocity to a weighting 
target of 1.0 to meet the requirements of Sec.  1066.110(b)(2)(iii)(C). 
Allow filter face velocity to decrease as a percentage of the weighting 
factor if the weighting factor is less than 1.0 and do not change the 
nominal CVS flowrates or secondary dilution ratios between FTP or UDDS 
test intervals. Use the appropriate equations in Sec.  1066.610 to show 
that you meet the dilution factor requirements of Sec.  
1066.110(b)(2)(iii)(B). If you collect PM using the procedures specified 
in paragraph (b)(4) or (5) of this section, the residence time 
requirements in 40 CFR 1065.140(e)(3) apply, except that you may exceed 
an overall residence time of 5.5 s for sample flow rates below the 
highest expected sample flow rate.
    (1) You may collect a separate PM sample for transient and 
stabilized portions of the cold-start UDDS and the hot-start UDDS. This 
may either be done by sampling with three bags or four bags. You may 
omit the stabilized portion of the hot-start test (bag 4) and use the 
stabilized portion of the cold-start test (bag 2) in its place.
    (2) You may collect PM on one filter over the cold-start UDDS and on 
a separate filter over the hot-start UDDS.
    (3) You may collect PM on one filter over the cold-start UDDS (bag 1 
and bag 2) and on a separate filter over the 867 seconds of the 
stabilized portion of the cold-start UDDS and the first 505 seconds of 
the hot-start UDDS (bag 2 and bag 3). Note that this option involves 
duplicate measurements during the stabilized portion of the cold-start 
UDDS.
    (4) You may collect PM on a single filter over the cold-start UDDS 
and the first 505 seconds of the hot-start UDDS using one of the 
following methods:
    (i) Adjust your sampling system flow rate over the filter to weight 
the filter face velocity over the three intervals of the FTP based on 
weighting targets of 0.43 for bag 1, 1.0 for bag 2, and 0.57 for bag 3.
    (ii) Maintain a constant sampling system flow rate over the filter 
for all three intervals of the FTP by increasing overall dilution ratios 
for bag 1 and bag 3. To do this, reduce the sample flow rate from the 
exhaust (or diluted exhaust) such that the value is reduced to 43% and 
57%, respectively, of the bag 2 values. For constant-volume samplers, 
this requires that you decrease the dilute exhaust sampling rate from 
the CVS and compensate for that by increasing the amount of secondary 
dilution air.
    (5) You may collect PM on a single filter over the cold-start UDDS 
and the full hot-start UDDS using one of the following methods:
    (i) Adjust your sampling system flow rate over the filter to weight 
the filter face velocity based on weighting targets of 0.75 for the 
cold-start UDDS and 1.0 for the hot-start UDDS.
    (ii) Maintain a constant sampling system flow rate over the filter 
for both the cold-start and hot-start UDDS by increasing the overall 
dilution ratio for the cold-start UDDS. To do this, reduce the sample 
flow rate from the exhaust (or diluted exhaust) such that the value is 
reduced to 75% of the hot-start UDDS value. For constant-volume 
samplers, this requires that you decrease the dilute exhaust sampling 
rate from the CVS and compensate for

[[Page 416]]

that by increasing the amount of secondary dilution air.
    (c) Gaseous sampling options. Collect gaseous samples using any of 
the following procedures:
    (1) You may collect a single sample for a full UDDS (cold-start or 
hot-start).
    (2) You may sample emissions separately for transient and stabilized 
portions of any UDDS.
    (3) You may omit the stabilized portion of the hot-start test (bag 
4) and use the stabilized portion of the cold-start test (bag 2) in its 
place.
    (d) Test sequence. Follow the exhaust emission measurement 
procedures specified in Sec. Sec.  1066.410 through 1066.425, subject to 
the following exceptions and additional provisions:
    (1) Take the following steps for the cold-start test:
    (i) Precondition the vehicle as described in Sec.  1066.816. 
Initiate the cold-start test following the 12 to 36 hour soak period.
    (ii) Simultaneously start any electronic integrating devices, 
continuous data recording, and batch sampling before attempting to start 
the engine. Initiate the sequence of points in the test cycle when the 
engine starts. Place the vehicle in gear 15 seconds after engine 
starting, which is 5 seconds before the first acceleration.
    (iii) At the end of the deceleration scheduled to occur 505 seconds 
into the cold-start UDDS, simultaneously switch all the sample flows 
from the cold-start transient interval to the stabilized interval, 
stopping all cold-start transient interval sampling and recording, 
including background sampling. Reset integrating devices for the 
stabilized interval and indicate the end of the cold-start interval in 
the recorded data. Operate the vehicle over the remainder of the UDDS. 
Turn the engine off 2 seconds after the end of the last deceleration in 
the stabilized interval (1,369 seconds after the start of the driving 
schedule).
    (iv) Five seconds after the engine stops running, stop all 
stabilized interval sampling and recording, including background 
sampling. Stop any integrating devices for the stabilized interval and 
indicate the end of the stabilized interval in the recorded data. Note 
that the 5 second delay is intended to account for sampling system 
transport.
    (2) Take the following steps for the hot-start test:
    (i) Initiate the hot-start test (9 to 11) minutes after the end of 
the sample period for the cold-start UDDS.
    (ii) Repeat the steps in paragraph (d)(1)(ii) of this section. 
Operate the vehicle over the first 505 seconds of the UDDS. For tests 
that do not include bag 4 operation, turn off the engine and 
simultaneously stop all hot-start sampling and recording, including 
background sampling, and any integrating devices at the end of the 
deceleration scheduled to occur 505 seconds into the hot-start UDDS.
    (iii) To include bag 4 measurement, operate the vehicles over the 
remainder of the UDDS and conclude the testing as described in 
paragraphs (d)(1)(iii) and (iv) of this section.
    (3) This completes the procedure for measuring FTP exhaust 
emissions. See Sec.  1066.801 and subpart J of this part for continuing 
the test sequence to measure evaporative or refueling emissions.

[79 FR 23823, Apr. 28, 2014, as amended at 80 FR 9124, Feb. 19, 2015; 81 
FR 74213, Oct. 25, 2016; 88 FR 4709, Jan. 24, 2023]



Sec.  1066.816  Vehicle preconditioning for FTP testing.

    Precondition the test vehicle before the FTP exhaust measurement as 
described in 40 CFR 86.132.



Sec.  1066.820  Composite calculations for FTP exhaust emissions.

    (a) Determine the mass of exhaust emissions of each pollutant for 
each FTP test interval as described in Sec.  1066.605.
    (b) Calculate the final composite gaseous test results as a mass-
weighted value, e[emission]-FTPcomp, in grams per mile using 
the following equation:

[[Page 417]]

[GRAPHIC] [TIFF OMITTED] TR28AP14.136

Where:

mc = the combined mass emissions determined from the cold-
          start UDDS test interval (generally known as bag 1 and bag 2), 
          in grams.
Dct = the measured driving distance from the transient 
          portion of the cold-start test (bag 1), in miles.
Dcs = the measured driving distance from the stabilized 
          portion of the cold-start test (bag 2), in miles.
mh = the combined mass emissions determined from the hot-
          start UDDS test interval in grams. This is the hot-stabilized 
          portion from either the first or second UDDS (bag 2, unless 
          you measure bag 4), in addition to the hot transient portion 
          (bag 3).
Dht = the measured driving distance from the transient 
          portion of the hot-start test (bag 3), in miles.
Dhs = the measured driving distance from the stabilized 
          portion of the hot-start test (bag 4), in miles. Set 
          Dhs = Dcs for testing where the hot-
          stabilized portion of the UDDS is not run.

    (c) Calculate the final composite PM test results as a mass-weighted 
value, ePM-FTPcomp, in grams per mile as follows:
    (1) Use the following equation for PM measured as described in Sec.  
1066.815(b)(1), (2), or (3):
[GRAPHIC] [TIFF OMITTED] TR25OC16.301


Where:

mPM-cUDDS = the combined PM mass emissions determined from 
          the cold-start UDDS test interval (bag 1 and bag 2), in grams, 
          as calculated using Eq. 1066.605-3.
mPM-hUDDS = the combined PM mass emissions determined from 
          the hot-start UDDS test interval (bag 3 and bag 4), in grams, 
          as calculated using Eq. 1066.605-3. This is the hot-stabilized 
          portion from either the first or second UDDS (bag 2, unless 
          you measure bag 4), in addition to the hot transient portion 
          (bag 3).

    (2) Use the following equation for PM measured as described in Sec.  
1066.815(b)(4):
[GRAPHIC] [TIFF OMITTED] TR25OC16.302


Where:

mPM = the combined PM mass emissions determined from the 
          cold-start UDDS test interval and the first 505 seconds of the 
          hot-start UDDS test interval (bag 1, bag 2, and bag 3), in 
          grams, as calculated using Eqs. 1066.605-4 and 1066.605-5.


[[Page 418]]


    (3) Use the following equation for PM measured as described in Sec.  
1066.815(b)(5):
[GRAPHIC] [TIFF OMITTED] TR25OC16.303


Where:

mPM = the combined PM mass emissions determined from the 
          cold-start UDDS test interval and the hot-start UDDS test 
          interval (bag 1, bag 2, bag 3, and bag 4), in grams, as 
          calculated using Eqs. 1066.605-6 and 1066.605-7.

[79 FR 23823, Apr. 28, 2016, as amended at 81 FR 74214, Oct. 25, 2016]



Sec.  1066.830  Supplemental Federal Test Procedures; overview.

    Sections 1066.831 and 1066.835 describe the detailed procedures for 
the Supplemental Federal Test Procedure (SFTP). This testing applies for 
all vehicles subject to the SFTP standards in 40 CFR part 86, subpart S. 
The SFTP test procedure consists of FTP testing and two additional test 
elements--a sequence of vehicle operation with more aggressive driving 
and a sequence of vehicle operation that accounts for the impact of the 
vehicle's air conditioner.
    (a) The SFTP standard applies as a composite representing the three 
test elements. The emission results from the aggressive driving test 
element (Sec.  1066.831), the air conditioning test element (Sec.  
1066.835), and the FTP test element (Sec.  1066.820) are analyzed 
according to the calculation methodology and compared to the applicable 
SFTP emission standards as described in 40 CFR part 86, subpart S.
    (b) The test elements of the SFTP may be run in any sequence that 
includes the specified preconditioning steps.



Sec.  1066.831  Exhaust emission test procedures for aggressive driving.

    (a) This section describes how to test using the US06 or LA-92 
driving schedule. The US06 driving schedule can be divided into two test 
intervals--the US06 City cycle comprises the combined portions of the 
cycle from 1 to 130 seconds and from 495 to 596 seconds, and the US06 
Highway cycle comprises the portion of the cycle between 130 and 495 
seconds. See Sec.  1066.801 for further information on the driving 
schedules.
    (b) Take the following steps to precondition vehicles for testing 
under this section:
    (1) Drain and refill the vehicle's fuel tank(s) in any of the 
following cases:
    (i) For aggressive-driving tests that do not follow FTP or HFET 
testing.
    (ii) For a test element that starts more than 72 hours after the 
most recent FTP or HFET measurement (with or without evaporative 
emission measurements).
    (iii) For testing in which the test vehicle has not remained in an 
area where ambient temperatures were within the range specified for 
testing since the previous FTP or HFET.
    (2) Keep ambient temperatures within the ranges specified for test 
measurements throughout the preconditioning sequence.
    (3) Warm up the vehicle to a stabilized condition as follows:
    (i) Push or drive the vehicle onto the dynamometer.
    (ii) Operate the vehicle one time over one of the driving schedules 
specified in this paragraph (b)(3)(ii). You may ask us to use a 
particular preconditioning driving schedule if that is related to fuel 
effects on adaptive memory systems. For our testing, we will generally 
operate the vehicle over the same preconditioning cycle that will be 
used for testing in this section. You may exercise your sampling 
equipment, but you may not determine

[[Page 419]]

emissions results during preconditioning. Choose from the following 
driving schedules:
    (A) The first 505 seconds of the UDDS (bag 1).
    (B) The last 867 seconds of the UDDS (bag 2).
    (C) The HFET driving schedule.
    (D) US06 driving schedule or, for heavy-duty vehicles at or below 
10,000 pounds GVWR with a power-to-weight ratio at or below 0.024 hp/
lbm, just the highway portion of the US06 driving schedule.
    (E) The SC03 driving schedule.
    (F) The LA-92 driving schedule.
    (G) The Hot LA-92 driving schedule.
    (4) Allow the vehicle to idle for (1 to 2) minutes. This leads 
directly into the test measurements described in paragraph (c) of this 
section.
    (c) For testing involving the full US06 driving schedule, you may 
collect emissions from separate city and highway test intervals (see 40 
CFR part 600), or you may collect emissions over the full US06 driving 
schedule as a single test interval. Take the following steps to measure 
emissions over separate city and highway test intervals:
    (1) At 130 seconds, simultaneously stop all US06 City, and start all 
US06 Highway sampling, recording, and integrating (including background 
sampling). At 136 seconds (before the acceleration), record the measured 
dynamometer roll revolutions.
    (2) At 495 seconds, simultaneously stop all US06 Highway, and start 
all US06 City sampling, recording, and integrating (including background 
sampling). At 500 seconds (before the acceleration), record the measured 
dynamometer roll revolutions.
    (3) Except as specified in paragraph (c)(4) of this section, treat 
the emissions from the first and second portions of the US06 City test 
interval as a single sample.
    (4) If you collect gaseous emissions over separate city and highway 
test intervals, you may still collect PM over the full US06 driving 
schedule as a single test interval. If you do this, calculate a 
composite dilution factor based on city and highway emissions using Eq. 
1066.610-4 to show that you meet the dilution factor requirements of 
Sec.  1066.110(b)(2)(iii)(B).
    (d) For diesel-fueled vehicles, measure THC emissions on a 
continuous basis. For separate measurement of the city and highway test 
intervals as described in paragraph (c) of this section, perform 
separate calculations for each portion of the test cycle.
    (e) Follow the exhaust emission measurement procedures specified in 
Sec. Sec.  1066.410 through 1066.425, subject to the following 
exceptions and additional provisions:
    (1) Following the preconditioning specified in paragraph (b) of this 
section, place the vehicle in gear and simultaneously start sampling and 
recording. Begin the first acceleration 5 seconds after placing the 
vehicle in gear.
    (2) Operate the vehicle over the full US06 driving schedule, except 
as follows:
    (i) For heavy-duty vehicles above 10,000 pounds GVWR, operate the 
vehicle over the Hot LA-92 driving schedule.
    (ii) Heavy-duty vehicles at or below 10,000 pounds GVWR with a 
power-to-weight ratio at or below 0.024 hp/lbm may be certified using 
only the highway portion of the US06 driving schedule as described in 40 
CFR 86.1816.
    (iii) Non-MDPV heavy-duty vehicles shall be tested at their adjusted 
loaded vehicle weight as described in 40 CFR 86.1816.
    (3) Turn the engine off 2 seconds after the end of the last 
deceleration. Five seconds after the engine stops running, stop all 
sampling and recording, including background sampling. Stop any 
integrating devices and indicate the end of the test cycle in the 
recorded data. Note that the 5 second delay is intended to account for 
sampling system transport.
    (4) Correct calculated NOX emissions as described in 
Sec.  1066.615(a)(1).

[79 FR 23823, Apr. 28, 2014, as amended at 80 FR 9124, Feb. 19, 2015; 88 
FR 4709, Jan. 24, 2023]



Sec.  1066.835  Exhaust emission test procedure for SC03 emissions.

    This section describes how to test using the SC03 driving schedule 
(see Sec.  1066.801). This procedure is designed to determine gaseous 
exhaust emissions while simulating an urban trip on a hot

[[Page 420]]

summer day. The provisions of 40 CFR part 86 and 40 CFR part 600 waive 
SC03 testing for some vehicles; in those cases, calculate SFTP composite 
emissions by adjusting the weighting calculation as specified in 40 CFR 
part 86, subpart S.
    (a) Drain and refill the vehicle's fuel tank(s) if testing starts 
more than 72 hours after the most recent FTP or HFET measurement (with 
or without evaporative emission measurements).
    (b) Keep the vehicle in an environment meeting the conditions 
described in paragraph (f) of this section throughout the 
preconditioning sequence.
    (c) Warm up the vehicle to a stabilized condition as follows:
    (1) Push or drive the test vehicle onto the dynamometer.
    (2) Close the vehicle's windows before testing.
    (3) The test cell and equipment must meet the specifications in 
paragraph (e) of this section. Measure and control ambient conditions as 
specified in paragraph (f) of this section.
    (4) Set the vehicle's air conditioning controls by selecting A/C 
mode and ``maximum'', setting airflow to ``recirculate'' (if so 
equipped), selecting the highest fan setting, and turning the A/C 
temperature to full cold (or 72 [deg]F for automatic systems). Turn the 
control to the ``on'' position before testing so the air conditioning 
system is active whenever the engine is running.
    (5) Perform a preconditioning drive by operating the test vehicle 
one time over the first 505 seconds of the UDDS (bag 1), the last 867 
seconds of the UDDS (bag 2), or the SC03 driving schedule. If the air 
conditioning test sequence starts more than 2 hours after a different 
exhaust emission test, you may instead operate the vehicle one time over 
the full UDDS.
    (6) Following the preconditioning drive, turn off the test vehicle 
and the vehicle cooling fan(s) and allow the vehicle to soak for (9 to 
11) minutes.
    (d) Follow the exhaust emission measurement procedures specified in 
Sec. Sec.  1066.410 through 1066.425, subject to the following 
exceptions and additional provisions:
    (1) Place the vehicle in gear 15 seconds after engine starting, 
which is 3 seconds before the first acceleration. Follow the SC03 
driving schedule.
    (2) Turn the engine off 2 seconds after the end of the last 
deceleration. Five seconds after the engine stops running, stop all 
sampling and recording, including background sampling. Stop any 
integrating devices any indicate the end of the test cycle in the 
recorded data. Note that the 5 second delay is intended to account for 
sampling system transport.
    (3) Correct calculated NOX emissions as described in 
Sec.  1066.615(a)(2).
    (e) The following requirements apply for the test cell and cooling 
fan configuration:
    (1) Minimum test cell size. The test cell must be at least 20 feet 
wide, 40 feet long, and 10 feet high, unless we approve the use of a 
smaller test cell. We will approve this only if you demonstrate that the 
smaller test cell is capable of meeting all the requirements of this 
section.
    (2) Vehicle frontal air flow. Verify that the fan configuration 
meets the requirements of Sec.  1066.105(c)(5).
    (f) Maintain ambient conditions as follows:
    (1) Ambient temperature and humidity. Measure and record ambient 
temperature and humidity in the test cell at least once every 30 seconds 
during the sampling period. Alternatively, if you collect data of at 
least once every 12 seconds, you may use a moving average of up to 30 
second intervals to measure and record ambient temperature and humidity. 
Control ambient temperature throughout the test sequence to (35.0  3.0) [deg]C. Control ambient temperature during 
emission sampling to (33.6 to 36.4) [deg]C on average. Control ambient 
humidity during emission sampling as described in Sec.  1066.420(d).
    (2) Conditions before testing. Use good engineering judgment to 
demonstrate that you meet the specified temperature and humidity 
tolerances in paragraph (f)(1) of this section during the 
preconditioning cycle and during the vehicle soak period in paragraph 
(c)(6) of this section.
    (3) Solar heat load. Simulate solar heating as follows:
    (i) You may use a metal halide lamp, a sodium lamp, or a quartz 
halogen lamp with dichroic mirrors as a radiant

[[Page 421]]

energy emitter. We may also approve the use of a different type of 
radiant energy emitter if you demonstrate that it meets the requirements 
of this section.
    (ii) We recommend achieving radiant heating with spectral 
distribution characteristics as described in the following table:

      Table 1 of Sec.   1066.835--Recommended Spectral Distribution
------------------------------------------------------------------------
                                                    Percent of total
                                                        spectrum
                Band width (nm)                -------------------------
                                                Lower limit  Upper limit
                                                    (%)          (%)
------------------------------------------------------------------------
<320 \a\......................................  ...........            0
320-400.......................................            0            7
400-780.......................................           45           55
780................................           35           53
------------------------------------------------------------------------
\a\ Note that you may need to filter the UV region between 280 and 320
  nm.

    (iii) Determine radiant energy intensity experienced by the vehicle 
as the average value between two measurements along the vehicle's 
centerline, one at the base of the windshield and the other at the 
bottom of the rear window (or equivalent location for vehicles without a 
rear window). This value must be (850  45) W/m\2\. 
Instruments for measuring radiant energy intensity must meet the 
following minimum specifications:
    (A) Sensitivity of 9 microvolts per W/m\2\.
    (B) Response time of 5 seconds. For purposes of this requirement, 
``response time'' means the time for the instrument to reach 95 percent 
of its equilibrium response after a step change in radiant intensity.
    (C) Cosine response error of no more than 1% 
for 0-70 degree zenith angles. The cosine response error is the 
percentage difference between the intensity measured at a given angle 
and a reference value, where the reference value is the intensity 
predicted from the zero-degree intensity and the cosine of the incident 
angle.
    (D) When comparing measured values for radiant energy to reference 
values, each measured value over the full range of measurement may not 
deviate from the corresponding reference value by more than 0.5% of the analyzer range's maximum value.
    (iv) Check the uniformity of radiant energy intensity at least every 
500 hours of emitter usage or every 6 months, whichever is sooner, and 
after any major modifications affecting the solar simulation. Determine 
uniformity by measuring radiant energy intensity using instruments that 
meet the specifications described in paragraph (f)(3)(iii) of this 
section at each point of a 0.5 m grid over the vehicle's full footprint, 
including the edges of the footprint, at an elevation 1 m above the 
floor. Measured values of radiant energy intensity must be between (722 
and 978) W/m\2\ at all points.

[79 FR 23823, Apr. 28, 2014, as amended at 80 FR 9124, Feb. 19, 2015; 81 
FR 74214, Oct. 25, 2016; 86 FR 34584, June 29, 2021; 88 FR 4709, Jan. 
24, 2023]



Sec.  1066.840  Highway fuel economy test procedure.

    This section describes the procedure for the highway fuel economy 
test (HFET). This test involves emission sampling and fuel economy 
measurement for certain vehicles as described in 40 CFR part 86, subpart 
S, and in 40 CFR part 600. See Sec.  1066.801 for further information on 
the driving schedules. Follow the exhaust emission measurement 
procedures specified in Sec. Sec.  1066.410 through 1066.425, subject to 
the following exceptions and additional provisions:
    (a) Perform the HFET immediately following the FTP when this is 
practical. If the HFET procedure starts more than 3 hours after an FTP 
(including evaporative emission measurements, if applicable), operate it 
over one UDDS to precondition the vehicle. We may approve additional 
preconditioning in unusual circumstances.
    (b) Operate the vehicle over the HFET driving schedule for 
preconditioning. Allow the vehicle to idle for 15 seconds (with the 
vehicle in gear), then start a repeat run of the HFET driving schedule 
and simultaneously start sampling and recording.
    (c) Turn the engine off at the end of the HFET driving schedule and 
stop all sampling and recording, including background. Stop any 
integrating devices and indicate the end of the test cycle in the 
recorded data.

[[Page 422]]



Sec.  1066.845  AC17 air conditioning efficiency test procedure.

    (a) Overview. This section describes a voluntary procedure for 
measuring the net impact of air conditioner operation on CO2 
emissions. See 40 CFR 86.1868 for provisions describing how to use these 
procedures to calculate credits and otherwise comply with emission 
standards.
    (b) Test cell. Operate the vehicle in a test cell meeting the 
specifications described in Sec.  1066.835(e). You may add airflow up to 
a maximum of 4 miles per hour during engine idling and when the engine 
is off if that is needed to meet ambient temperature or humidity 
requirements.
    (c) Ambient conditions. Measure and control ambient conditions as 
specified in Sec.  1066.835(f), except that you must control ambient 
temperature during emission sampling to (22.0 to 28.0) [deg]C throughout 
the test and (23.5 to 26.5) [deg]C on average. These tolerances apply to 
the combined SC03 and HFET drive cycles during emission sampling. Note 
that you must set the same ambient temperature target for both the air 
conditioning on and off portions of emission sampling. Control ambient 
temperature during the preconditioning cycle and 30 minute soak to (25.0 
 5.0) [deg]C. For these same modes with no 
emission sampling, target the specified ambient humidity levels, but you 
do not need to meet the humidity tolerances. Note that solar heating is 
disabled for certain test intervals as described in this section.
    (d) Interior air temperature measurement. Measure and record the 
vehicle's interior air temperature at least once every 5 seconds during 
the sampling period. Measure temperature at the outlet of the center-
most duct on the dashboard, and approximately 30 mm behind the driver's 
headrest and passenger's headrest.
    (e) Air conditioning system settings. For testing that requires the 
air conditioning to be operating, set the vehicle's air conditioning 
controls as follows:
    (1) For automatic systems, set the temperature control to 72 [deg]F 
(22 [deg]C).
    (2) For manual systems, select A/C mode, set the temperature to full 
cold and ``maximum'', set airflow to ``recirculate'' (if so equipped), 
and select the highest fan setting. During the first idle period of the 
SC03 driving schedule (between 186 and 204 seconds), reduce the fan 
speed setting to nominally 50% of maximum fan speed, set airflow to 
``fresh air'' (if so equipped), and adjust the temperature setting to 
target a temperature of 55 [deg]F (13 [deg]C) at the dashboard air 
outlet. Maintain these settings for the remainder of the test. You may 
rely on prior temperature measurements to determine the temperature 
setting; however, if the system is unable to meet the 55 [deg]F (13 
[deg]C) target, you may instead set airflow to ``fresh air'' and 
temperature to full cold. If the vehicle is equipped with technology 
that defaults to recirculated air at ambient temperatures above 75 
[deg]F (22 [deg]C), that technology should remain enabled throughout the 
test; this may mean not setting the airflow to ``recirculate'' at the 
start and not setting the airflow to ``fresh air'' during the first idle 
period of the SC03 driving schedule. Except as specified in paragraph 
(e)(3) of this section, use good engineering judgment to apply the 
settings described in this paragraph (e)(2) equally throughout the 
vehicle if there are separate controls for different zones (such as rear 
air conditioning).
    (3) If the air conditioning system is designed with parameters that 
switch back to a default setting at key-off, perform testing in that 
default condition. If the air conditioning system includes any optional 
equipment or user controls not addressed in this paragraph (e), the 
manufacturer should ask us for preliminary approval to determine the 
appropriate settings for testing.
    (f) Test procedure. Follow the exhaust emission measurement 
procedures specified in Sec. Sec.  1066.410 through 1066.425, subject to 
the following exceptions and additional provisions:
    (1) Prepare each test vehicle for a series of tests according to 40 
CFR 86.132-00(a) through (g). If the vehicle has been tested within the 
last 36 hours concluding with a 12 to 36 hour soak, continue to 
paragraph (f)(2) of this section; otherwise perform an additional UDDS 
preconditioning cycle that concludes with a 12 to 36 hour soak. You may 
use a forced cooldown system to

[[Page 423]]

bring critical vehicle temperatures to within soak temperature limits. 
Critical temperatures include transmission oil, engine oil, engine 
coolant, and cabin air temperatures.
    (2) Open the vehicle's windows and operate the vehicle over a 
preconditioning UDDS with no solar heating and with the air conditioning 
off. At the end of the preconditioning drive, turn off the test vehicle 
and all cooling fans.
    (3) Turn on solar heating within one minute after turning off the 
engine. Once the solar energy intensity reaches 805 W/m\2\, let the 
vehicle soak for (30  1) minutes. You may 
alternatively rely on prior measurements to start the soak period after 
a defined period of warming up to the specified solar heat load. Close 
the vehicle's windows at the start of the soak period; ensure that the 
windows are adequately closed where instrumentation and wiring pass 
through to the interior.
    (4) Turn the air conditioning control to the ``on'' position before 
testing so the air conditioning system is active whenever the engine is 
running. Place the vehicle in gear 15 seconds after engine starting, 
which is 3 seconds before the first acceleration. At the end of the 
driving schedule, simultaneously switch all the sampling, recording, and 
integrating from SC03 to HFET, including background sampling. Indicate 
the end of the test cycle in the recorded data. Record the measured 
dynamometer roll revolutions corresponding to the SC03 driving schedule.
    (5) Directly following the SC03 driving schedule, operate the 
vehicle over the HFET driving schedule. Turn the vehicle off at the end 
of the driving schedule and simultaneously stop all sampling, recording, 
and integrating, including background sampling. Indicate the end of the 
test cycle in the recorded data. Record the measured dynamometer roll 
revolutions corresponding to the HFET drive schedule. Turn off the solar 
heating.
    (6) Allow the vehicle to remain on the dynamometer for (10 to 15) 
minutes after emission sampling has concluded. Repeat the testing 
described in paragraphs (f)(1) through (5) of this section and turn off 
the vehicle's air conditioner and the solar heating throughout the test 
run. The windows may be open or closed.
    (g) Calculations. (1) Determine the mass of CO2 emissions 
for each of the two test intervals as described in Sec.  1066.605.
    (2) Calculate separate composite mass-weighted emissions of 
CO2, eCO2-AC17compAC[status], representing the 
average of the SC03 and HFET emissions, in grams per mile for operation 
with the vehicle's air conditioner and the solar heating on and off 
using the following equation:
[GRAPHIC] [TIFF OMITTED] TR24JA23.162

Where:

mSC03 = mass emissions from the SC03 test interval, in grams.
DSC03 = measured driving distance during the SC03 test 
          interval, in miles.
mHFET = mass emissions from the HFET test interval, in grams.
DHFET = measured driving distance during the HFET test 
          interval, in miles.

    (3) Calculate the incremental CO2 emissions due to air 
conditioning operation by subtracting the composite mass-weighted 
emissions of CO2 with the vehicle's air conditioner and the 
solar heating on, eCO2-AC17compACon, from the composite mass-
weighted emissions of CO2 with the vehicle's air conditioner 
and the solar heating off, eCO2-AC17compACoff.
    (h) Record information for each test as specified in Sec.  1066.695. 
Emission results and the results of all calculations must be reported 
for each phase of the test. The manufacturer must also report the 
following information for each

[[Page 424]]

vehicle tested: interior volume, climate control system type and 
characteristics, refrigerant used, compressor type, and evaporator/
condenser characteristics.

[79 FR 23823,Apr. 28, 2014, as amended at 79 FR 36658, June 30, 2014; 80 
FR 9124, Feb. 19, 2015; 88 FR 4710, Jan. 24, 2023]



             Subpart J_Evaporative Emission Test Procedures



Sec.  1066.901  Applicability and general provisions.

    This subpart describes how to measure evaporative and refueling 
emissions from test vehicles. The provisions of Sec. Sec.  1066.910 
through 1066.930 include general provisions for equipment and 
calculations related to evaporative and refueling emissions. The 
provisions of Sec. Sec.  1066.950 through 1066.985 describe provisions 
that apply specifically to motor vehicles subject to standards under 40 
CFR part 86, subpart S, or 40 CFR part 1037.

 Test Equipment and Calculations for Evaporative and Refueling Emissions



Sec.  1066.910  SHED enclosure specifications.

    Enclosures for evaporative and refueling emissions must meet the 
specifications described in 40 CFR 86.106-96, 86.107-96(a), and 86.107-
98(a).



Sec.  1066.915  Enclosures; auxiliary systems and equipment.

    Enclosures for evaporative and refueling emissions must be equipped 
with fans, blowers, and measurement and data recording equipment as 
described in 40 CFR 86.107-98(b) through (h) and (j).



Sec.  1066.920  Enclosure calibrations.

    Enclosures for evaporative and refueling emissions must meet the 
calibration specifications described in 40 CFR 86.116-94 and 86.117-96.



Sec.  1066.925  Enclosure calculations for evaporative and refueling emissions.

    Calculate emissions for evaporative emissions as described in 40 CFR 
86.143-96. Calculate emissions for refueling emissions as described in 
40 CFR 86.143-96 and 86.156-98.



Sec.  1066.930  Equipment for point-source measurement of running losses.

    For point-source measurement of running loss emissions, use 
equipment meeting the specifications in 40 CFR 86.107-96(i).

[86 FR 34585, June 29, 2021]

  Evaporative and Refueling Emission Test Procedures for Motor Vehicles



Sec.  1066.950  Fuel temperature profile.

    Develop fuel temperature profiles for running loss testing as 
described in 40 CFR 86.129-94(d).



Sec.  1066.955  Diurnal emission test.

    Test vehicles for diurnal emissions as described in 40 CFR 86.133-
96.



Sec.  1066.960  Running loss test.

    Test vehicles for running loss emissions as described in 40 CFR 
86.134-96.



Sec.  1066.965  Hot soak test.

    Test vehicles for hot soak emissions as described in 40 CFR 86.138-
96.



Sec.  1066.970  Refueling test for liquid fuels.

    Except as described in Sec.  1066.975, test vehicles for refueling 
emissions as described in 40 CFR 86.150-98, 86.151-98, 86.152-98, and 
86.154-98. Keep records as described in 40 CFR 86.155-98.



Sec.  1066.971  Vehicle and canister preconditioning for the refueling test.

    Precondition vehicles for the refueling emission test as described 
in 40 CFR 86.153-98.



Sec.  1066.975  Refueling test for LPG.

    For vehicles designed to operate on liquefied petroleum gas, measure 
refueling emissions as described in 40 CFR 86.157-98.



Sec.  1066.980  Fuel dispensing spitback procedure.

    Test vehicles for spitback emissions as described in 40 CFR 86.146-
96.

[[Page 425]]



Sec.  1066.985  Fuel storage system leak test procedure.

    (a) Scope. Perform this test as required in the standard-setting 
part to verify that there are no significant leaks in your fuel storage 
system.
    (b) Measurement principles. Leaks are detected by measuring 
pressure, temperature, and flow to calculate an equivalent orifice 
diameter for the system. Use good engineering judgment to develop and 
implement leak test equipment. You may not tighten fittings or 
connections in the vehicle's fuel system to prepare the vehicle for 
testing.
    (c) Measurement equipment. Your leak test equipment must meet the 
following requirements:
    (1) Pressure, temperature, and flow sensors must be calibrated with 
NIST-traceable standards.
    (2) Correct flow measurements to standard reference conditions.
    (3) Leak test equipment must have the ability to pressurize fuel 
storage systems to at least 4.1 kPa and have an internal leak rate of 
less than 0.20 standard liters per minute.
    (4) You must be able to attach the test equipment to the vehicle 
without permanent alteration of the fuel storage or evaporative emission 
control systems. For any testing that involves pressurizing the fuel 
system and detecting leaks at access points away from the fuel fill 
pipe, the gas cap must be installed in the production configuration. For 
the test point at or near the fuel fill pipe, attaching the test 
equipment may involve adding an extension to the fuel fill pipe that 
incorporates the access point to the fuel system. If the extension 
apparatus has a fixed cap, the vehicle's gas cap must be tested 
separately as described in paragraph (d)(9) of this section. This 
separate testing is not required if the extension apparatus incorporates 
the vehicle's gas cap.
    (5) The point of attachment to the fuel storage system must allow 
pressurization to test system integrity of the fuel tank and of fuel 
lines and vapor lines reaching up to and including the gas cap and the 
evaporative canister. The evaporative system test port available on some 
vehicles is an example of an effective attachment point.
    (d) Leak test procedure. Test a vehicle's fuel storage system for 
leaks as follows:
    (1) Refuel vehicle to 40% of its nominal fuel tank capacity.
    (2) Soak the vehicle for 6 to 24 hours at a temperature between (20 
and 30) [deg]C; record this setpoint temperature and maintain 
temperatures throughout the leak test at this setpoint temperature 
within a tolerance 2 [deg]C.
    (3) Before performing the test, purge the fuel storage system of any 
residual pressure, bringing the system into equilibrium with ambient 
pressure.
    (4) Seal the evaporative canister's vent to atmosphere and ensure 
that the vehicle's purge valve is closed.
    (5) Attach the leak test equipment to the vehicle.
    (6) Pressurize the fuel storage system with N2 or another 
inert gas 9392..........................to at least 2.4 kPa. Use good 
engineering judgment to avoid overpressurizing the system.
    (7) Maintain gas flow through the system for at least 180 seconds, 
ensuring that the flow reading is stable for an effective leak diameter 
of 0.002 inches.
    (8) Use the following equation, or a different equation you develop 
based on good engineering judgment, to calculate the effective leak 
diameter, deff:

[[Page 426]]

[GRAPHIC] [TIFF OMITTED] TR25OC16.304


Where:

deff = effective leak diameter, in inches, expressed to at 
          least two decimal places.
QN2= volumetric flow of nitrogen, in m\3\/s.
pin = inlet pressure to orifice, in kPa.
patmos = atmospheric pressure, in kPa.
SGN2 = specific gravity of N2 relative to air at 
          101.325 kPa and 15.5 [deg]C = 0.967.
T = temperature of flowing medium, in K.

    Example: 

QN2= 0.8[middot]10-5 m\3\/s
pin = 104.294 kPa
patmos = 101.332 kPa
SGN2 = 0.967
T = 298.15 K
[GRAPHIC] [TIFF OMITTED] TR25OC16.305

    deff = 0.017 inches

    (9) Repeat the test described in this paragraph (d) for each access 
point described in the application for certification. Use each test 
result (without averaging) to determine whether the vehicle passes the 
leak standard.
    (10) Gas caps may need to be tested separately for leaks as 
described in paragraph (c)(4) of this section. Test the gas caps using 
commercially available flow equipment such as that used for inspection-
and-maintenance programs for motor vehicles to determine a leak rate in 
cubic centimeters per minute resulting from a sustained tank pressure of 
7.5 kPa. Correct the leak rate to standard reference conditions, based 
on the measured leak rate corresponding to atmospheric pressure. The 
corrected leak value may not exceed 60 cubic centimeters per minute.
    (11) You may use special or alternative test procedures as described 
in 40 CFR 1065.10(c).
    (e) Equipment calibration. Use good engineering judgment to 
calibrate the leak check device.

[79 FR 23823, Apr. 28, 2014, as amended at 80 FR 9124, Feb. 19, 2015; 81 
FR 74215, Oct. 25, 2016]



           Subpart K_Definitions and Other Reference Material



Sec.  1066.1001  Definitions.

    The definitions in this section apply to this part. The definitions 
apply to all subparts unless we note otherwise. Other terms have the 
meaning given in 40 CFR part 1065. The definitions follow:
    Average means the arithmetic mean of a sample.
    Bag 1 means relating to the first 505 seconds of the FTP cold-start 
test interval. Note that the term bag 1 may also apply to measurement of 
constituents that are not collected in a bag,

[[Page 427]]

such as PM and continuously measured THC.
    Bag 2 means relating to the last 867 seconds of the FTP cold-start 
test interval.
    Bag 3 means relating to the first 505 seconds of the FTP hot-start 
test interval.
    Bag 4 means relating to the last 867 seconds of the FTP hot-start 
test interval, if run. Note that bag 2 is generally used in place of bag 
4.
    Base inertia means a value expressed in mass units to represent the 
rotational inertia of the rotating dynamometer components between the 
vehicle driving tires and the dynamometer torque-measuring device, as 
specified in Sec.  1066.250.
    C1-equivalent means a convention of expressing HC 
concentrations based on the total number of carbon atoms present, such 
that the C1-equivalent of an HC concentration equals the 
concentration multiplied by the mean number of carbon atoms in each HC 
molecule. For example, the C1-equivalent of 10 ppm of propane 
(C3H8) is 30 ppm. C1-equivalent 
concentration values may be denoted as ``ppmC'' in the standard-setting 
part. Densities may also be expressed on a C1 basis. Note 
that calculating HC masses from concentrations and densities is only 
valid where they are each expressed on the same carbon basis.
    Charge-depleting means relating to the test interval of a plug-in 
hybrid engine or powertrain in which the engine or powertrain consumes 
electric energy from the RESS that has been charged from an external 
power source until the RESS is depleted to the point that a test 
interval qualifies as charge-sustaining. The engine might consume fuel 
to produce power during a charge-depleting test interval.
    Charge-sustaining means relating to the test interval of a plug-in 
hybrid engine or powertrain in which the engine or powertrain consumes 
fuel to produce power such that the battery's net-energy change meets 
the end-of-test criterion of SAE J1711 or SAE J2711, as applicable 
(incorporated by reference in Sec.  1066.1010).
    Driving schedule means a series of vehicle speeds that a vehicle 
must follow during a test. Driving schedules are specified in the 
standard-setting part. A driving schedule may consist of multiple test 
intervals.
    Duty cycle means a set of weighting factors and the corresponding 
test cycles, where the weighting factors are used to combine the results 
of multiple test intervals into a composite result.
    FTP means one of the following:
    (1) The test cycle consisting of one UDDS as specified in paragraph 
(a) of Appendix I of 40 CFR part 86, followed by a 10-minute soak with 
the engine off and repeat driving through the first 505 seconds of the 
UDDS. See Sec.  1066.801(c)(1).
    (2) The entire test procedure for measuring exhaust and/or 
evaporative emissions as described in Sec.  1066.801(c).
    Footprint has the meaning given in the standard-setting part.
    HFET means the test cycle specified in Appendix I of 40 CFR part 
600.
    Hot LA-92 means the first 1435 seconds of the LA-92 driving 
schedule.
    LA-92 means the test cycle specified in Appendix I, paragraph (c), 
of 40 CFR part 86.
    Nonmethane organic gas (NMOG) means the combination of organic gases 
other than methane as calculated in Sec.  1066.635. Note that for this 
part, the organic gases are summed on a mass basis without any 
adjustment for photochemical reactivity.
    Parts-per-million (ppm) means ppm on a molar basis. For hydrocarbon 
concentrations including HC, THC, NMHC, and NMOG, ppm means ppm on a 
C1-equivalent molar basis.
    Road-load coefficients means sets of A, B, and C road-load force 
coefficients that are used in the dynamometer road-load simulation, 
where road-load force at speed v equals A + B [middot] v + C [middot] 
v\2\.
    SC03 means the test cycle specified in Appendix I, paragraph (h), of 
40 CFR part 86.
    SFTP means the collection of test cycles as given in 1066.801(c)(2).
    Standard reference conditions means the following:
    (1) Standard pressure is 101.325 kPa.
    (2) Standard temperature is 293.15 K.
    Test interval means a period over which a vehicle's emission rates 
are determined separately. For many standards, compliance with the 
standard is

[[Page 428]]

based on a weighted average of the mass emissions from multiple test 
intervals. For example, the standard-setting part may specify a complete 
duty cycle as a cold-start test interval and a hot-start test interval. 
In cases where multiple test intervals occur over a duty cycle, the 
standard-setting part may specify additional calculations that weight 
and combine results to arrive at composite values for comparison against 
the applicable standards in this chapter.
    Test weight has the meaning given in Sec. Sec.  1066.410(b) or 
1066.805.
    UDDS means the test cycle specified in Appendix I, paragraph (a), of 
40 CFR part 86.
    US06 means the test cycle specified in Appendix I, paragraph (g), of 
40 CFR part 86.
    Unloaded coastdown means a dynamometer coastdown run with the 
vehicle wheels removed from the roll surface.
    We (us, our) means the Administrator of the Environmental Protection 
Agency and any authorized representatives.

[79 FR 23823, Apr. 28, 2014, as amended at 80 FR 9124, Feb. 19, 2015; 88 
FR 4710, Jan. 24, 2023]



Sec.  1066.1005  Symbols, abbreviations, acronyms, and units of measure.

    The procedures in this part generally follow either the 
International System of Units (SI) or the United States customary units, 
as detailed in NIST Special Publication 811, which we incorporate by 
reference in Sec.  1066.1010. See 40 CFR 1065.20 for specific provisions 
related to these conventions. This section summarizes the way we use 
symbols, units of measure, and other abbreviations.
    (a) Symbols for quantities. This part uses the following symbols and 
units of measure for various quantities:

                               Table 1 of Sec.   1066.1005--Symbols for Quantities
----------------------------------------------------------------------------------------------------------------
                                                                                               Unit in terms of
             Symbol                    Quantity              Unit             Unit symbol        SI base units
----------------------------------------------------------------------------------------------------------------
[alpha].........................  atomic hydrogen to  mole per mole.....  mol/mol...........  1.
                                   carbon ratio.
A...............................  area..............  square meter......  m2................  m2.
A...............................  vehicle frictional  pound force or      lbf or N..........  m[middot]kg[middot
                                   load.               newton.                                 ]s-2.
ag..............................  acceleration of     meters per second   m/s2..............  m[middot]s-2.
                                   Earth's gravity.    squared.
Am..............................  calculated vehicle  pound force or      lbf or N..........  m[middot]kg[middot
                                   frictional load.    newton.                                 ]s-2.
a0..............................  intercept of least
                                   squares
                                   regression.
a1..............................  slope of least
                                   squares
                                   regression.
a...............................  acceleration......  feet per second     ft/s2 or m/s2.....  m[middot]s	2.
                                                       squared or meters
                                                       per second
                                                       squared.
B...............................  vehicle load from   pound force per     lbf/(mi/hr) or      kg[middot]s	1.
                                   drag and rolling    mile per hour or    N[middot]s/m.
                                   resistance.         newton second per
                                                       meter.
[beta]..........................  ratio of diameters  meter per meter...  m/m...............  1.
[beta]..........................  atomic oxygen to    mole per mole.....  mol/mol...........  1.
                                   carbon ratio.
c...............................  conversion factor.
C...............................  vehicle-specific    pound force per     lbf/(mi/hr)2 or     m	1[middot]kg.
                                   aerodynamic         mile per hour       N[middot]s2/m2.
                                   effects.            squared or newton-
                                                       second squared
                                                       per meter squared.
C..............................  number of carbon    C................  number of carbon    C.
                                   atoms in a                              atoms in a
                                   molecule.                               molecule.
Cd..............................  discharge
                                   coefficient.
CdA.............................  drag area.........  meter squared.....  m2................  m2.
Cf..............................  flow coefficient.
Cp..............................  heat capacity at    joule per kelvin..  J/K...............  m2[middot]kg[middo
                                   constant pressure.                                          t]s-2[middot]K-1.
Cv..............................  heat capacity at    joule per kelvin..  J/K...............  m2[middot]kg[middo
                                   constant volume.                                            t]s-2[middot]K-1.
d...............................  diameter..........  meters............  m.................  m.
D...............................  distance..........  miles or meters...  mi or m...........  m.
D...............................  slope correlation.  pound force per     lbf/(mi/hr)2 or     m-2[middot]kg.
                                                       mile per hour       N[middot]s2/m2.
                                                       squared or newton
                                                       second squared
                                                       per meter squared.
DF..............................  dilution factor...  ..................  ..................  1.
e...............................  mass weighted       grams/mile........  g/mi.
                                   emission result.
F...............................  force.............  pound force or      lbf or N..........  kg[middot]s-2.
                                                       newton.
[fnof]..........................  frequency.........  hertz.............  Hz................  s-1.
[fnof]n.........................  angular speed       revolutions per     r/min.............  [pi][middot]30[mid
                                   (shaft).            minute.                                 dot]s-1.
FC..............................  friction            horsepower or watt  W.................  m2[middot]kg[middo
                                   compensation                                                t]s-3.
                                   error.
FR..............................  road-load force...  pound force or      lbf or N..........  kg[middot]s-2.
                                                       newton.

[[Page 429]]

 
[gamma].........................  ratio of specific   (joule per          (J/(kg[middot]K))/  1.
                                   heats.              kilogram kelvin)    (J/(kg[middot]K)).
                                                       per (joule per
                                                       kilogram kelvin).
H...............................  ambient humidity..  grams water vapor   g H2O vapor/kg dry  g H2O vapor/kg dry
                                                       per kilogram dry    air.                air.
                                                       air.
[Delta]h........................  change in height..  meters............  m.................  m.
I...............................  inertia...........  pound mass or       lbm or kg.........  kg.
                                                       kilogram.
I...............................  current...........  ampere............  A.................  A.
i...............................  indexing variable.
IR..............................  inertia work
                                   rating.
K...............................  correction factor.  ..................  ..................  1.
Kv..............................  calibration         ..................  m4[middot]s[middot  m4[middot]kg-
                                   coefficient.                            ]K0.5/kg.           1[middot]s[middot
                                                                                               ]K0.5.
[micro].........................  viscosity, dynamic  pascal second.....  Pa[middot]s.......  m-
                                                                                               1[middot]kg[middo
                                                                                               t]s-1.
M...............................  molar mass........  gram per mole.....  g/mol.............  10-3[middot]kg[mid
                                                                                               dot]mol-1.
Me..............................  effective mass....  kilogram..........  kg................  kg.
m...............................  mass..............  pound mass or       lbm or kg.........  kg.
                                                       kilogram.
N...............................  total number in
                                   series.
n...............................  total number of
                                   pulses in a
                                   series.
p...............................  pressure..........  pascal............  Pa................  m-
                                                                                               1[middot]kg[middo
                                                                                               t]s-2.
[Delta]p........................  differential        pascal............  Pa................  m-
                                   static pressure.                                            1[middot]kg[middo
                                                                                               t]s-2.
pd..............................  saturated vapor     kilopascal........  kPa...............  m-
                                   pressure at                                                 1[middot]kg[middo
                                   ambient dry bulb                                            t]s-1.
                                   temperature.
PF..............................  penetration
                                   fraction.
[rho]...........................  mass density......  kilogram per cubic  kg/m3.............  m-3[middot]kg.
                                                       meter.
R...............................  dynamometer roll    revolutions per     rpm...............  [pi][middot]30-
                                   revolutions.        minute.                                 1[middot]s-1.
r...............................  ratio of pressures  pascal per pascal.  Pa/Pa.............  1.
r2..............................  coefficient of
                                   determination.
Re.............................  Reynolds number.
RF..............................  response factor.
RH..............................  relative humidity.
S...............................  Sutherland          kelvin............  K.................  K.
                                   constant.
SEE.............................  standard error of
                                   the estimate.
SG..............................  specific gravity.
[Delta]s........................  distance traveled   meters............  m.................  m.
                                   during
                                   measurement
                                   interval.
T...............................  absolute            kelvin............  K.................  K.
                                   temperature.
T...............................  Celsius             degree Celsius....   [deg]C...........  K-273.15.
                                   temperature.
T...............................  torque (moment of   newton meter......  N[middot]m........  m2[middot]kg[middo
                                   force).                                                     t]s-2.
t...............................  time..............  hour or second....  hr or s...........  s.
[Delta]t........................  time interval,      second............  s.................  s.
                                   period, 1/
                                   frequency.
U...............................  voltage...........  volt..............  V.................  m2[middot]kg[middo
                                                                                               t]s-3[middot]A-1.
v...............................  speed.............  miles per hour or   mi/hr or m/s......  m[middot]s-1.
                                                       meters per second.
V...............................  volume............  cubic meter.......  m3................  m3.
V...............................  flow volume rate..  cubic feet per      ft3/min or m3/s...  m3[middot]/s-1.
                                                       minute or cubic
                                                       meter per second.
VP..............................  volume percent.
x...............................  concentration of    part per million..  ppm.
                                   emission over a
                                   test interval.
y...............................  generic variable.
Z...............................  compressibility
                                   factor.
----------------------------------------------------------------------------------------------------------------

    (b) Symbols for chemical species. This part uses the following 
symbols for chemical species and exhaust constituents:

   Table 2 to Paragraph (b) of Sec.   1066.1005--Symbols for Chemical
                    Species and Exhaust Constituents
------------------------------------------------------------------------
              Symbol                               Species
------------------------------------------------------------------------
CH4...............................  methane.
CH3OH.............................  methanol.
CH2O..............................  formaldehyde.
C2H4O.............................  acetaldehyde.
C2H5OH............................  ethanol.
C2H6..............................  ethane.
C3H7OH............................  propanol.
C3H8..............................  propane.
C4H10.............................  butane.
C5H12.............................  pentane.
CO................................  carbon monoxide.
CO2...............................  carbon dioxide.
H2O...............................  water.
HC................................  hydrocarbon.
N2................................  molecular nitrogen.
NMHC..............................  nonmethane hydrocarbon.

[[Page 430]]

 
NMHCE.............................  nonmethane hydrocarbon equivalent.
NMOG..............................  nonmethane organic gas.
NO................................  nitric oxide.
NO2...............................  nitrogen dioxide.
NOX...............................  oxides of nitrogen.
N2O...............................  nitrous oxide.
O2................................  molecular oxygen.
OHC...............................  oxygenated hydrocarbon.
PM................................  particulate matter.
THC...............................  total hydrocarbon.
THCE..............................  total hydrocarbon equivalent.
------------------------------------------------------------------------

    (c) Superscripts. This part uses the following superscripts for 
modifying quantity symbols:

                Table 3 of Sec.   1066.1005--Superscripts
------------------------------------------------------------------------
                Superscript                            Meaning
------------------------------------------------------------------------
overbar (such as y).......................  arithmetic mean.
overdot (such as y).......................  quantity per unit time.
------------------------------------------------------------------------

    (d) Subscripts. This part uses the following subscripts for 
modifying quantity symbols:

                 Table 4 of Sec.   1066.1005--Subscripts
------------------------------------------------------------------------
                 Subscript                             Meaning
------------------------------------------------------------------------
0.........................................  reference.
abs.......................................  absolute quantity.
AC17......................................  air conditioning 2017 test
                                             interval.
act.......................................  actual or measured
                                             condition.
actint....................................  actual or measured condition
                                             over the speed interval.
adj.......................................  adjusted.
air.......................................  air, dry.
atmos.....................................  atmospheric.
b.........................................  base.
bkgnd.....................................  background.
c.........................................  cold.
comp......................................  composite.
cor.......................................  corrected.
cs........................................  cold stabilized.
ct........................................  cold transient.
cUDDS.....................................  cold-start UDDS.
D.........................................  driven.
dew.......................................  dewpoint.
dexh......................................  dilute exhaust quantity.
dil.......................................  dilute.
e.........................................  effective.
emission..................................  emission specie.
error.....................................  error.
EtOH......................................  ethanol.
exh.......................................  raw exhaust quantity.
exp.......................................  expected quantity.
fil.......................................  filter.
final.....................................  final.
flow......................................  flow measurement device
                                             type.
gas.......................................  gaseous.
h.........................................  hot.
HFET......................................  highway fuel economy test.
hs........................................  hot stabilized.
ht........................................  hot transient.
hUDDS.....................................  hot-start UDDS.
i.........................................  an individual of a series.
ID........................................  driven inertia.
in........................................  inlet.
int.......................................  intake.
init......................................  initial quantity, typically
                                             before an emission test.
IT........................................  target inertia.
liq.......................................  liquid.
max.......................................  the maximum (i.e., peak)
                                             value expected at the
                                             standard over a test
                                             interval; not the maximum
                                             of an instrument range.
meas......................................  measured quantity.
mix.......................................  dilute exhaust gas mixture.
out.......................................  outlet.
PM........................................  particulate matter.
record....................................  record.
ref.......................................  reference quantity.
rev.......................................  revolution.
roll......................................  dynamometer roll.
s.........................................  settling.
s.........................................  slip.
s.........................................  stabilized.
sat.......................................  saturated condition.
SC03......................................  air conditioning driving
                                             schedule.
span......................................  span quantity.
sda.......................................  secondary dilution air.
std.......................................  standard conditions.
T.........................................  target.
t.........................................  throat.
test......................................  test quantity.
uncor.....................................  uncorrected quantity.
w.........................................  weighted.
zero......................................  zero quantity.
------------------------------------------------------------------------

    (d) Subscripts. This part uses the following subscripts to define a 
quantity:

------------------------------------------------------------------------
             Subscript                            Quantity
------------------------------------------------------------------------
0.................................  reference.
abs...............................  absolute quantity.
AC17..............................  air conditioning 2017 test interval.
act...............................  actual or measured condition.
actint............................  actual or measured condition over
                                     the speed interval.
adj...............................  adjusted.
air...............................  air, dry.
atmos.............................  atmospheric.
b.................................  base.
bkgnd.............................  background.
c.................................  cold.
comp..............................  composite.
cor...............................  corrected.
cs................................  cold stabilized.
ct................................  cold transient.
cUDDS.............................  cold-start UDDS.
D.................................  driven.
dew...............................  dewpoint.
dexh..............................  dilute exhaust quantity.
dil...............................  dilute.
e.................................  effective.
emission..........................  emission specie.
error.............................  error.
EtOH..............................  ethanol.
exh...............................  raw exhaust quantity.

[[Page 431]]

 
exp...............................  expected quantity.
fil...............................  filter.
final.............................  final.
flow..............................  flow measurement device type.
gas...............................  gaseous.
h.................................  hot.
HFET..............................  highway fuel economy test.
hs................................  hot stabilized.
ht................................  hot transient.
hUDDS.............................  hot-start UDDS.
i.................................  an individual of a series.
ID................................  driven inertia.
in................................  inlet.
int...............................  intake.
init..............................  initial quantity, typically before
                                     an emission test.
IT................................  target inertia.
liq...............................  liquid.
max...............................  the maximum (i.e. peak) value
                                     expected at the standard over a
                                     test interval; not the maximum of
                                     an instrument range.
meas..............................  measured quantity.
mix...............................  dilute exhaust gas mixture.
out...............................  outlet.
PM................................  particulate matter.
record............................  record.
ref...............................  reference quantity.
rev...............................  revolution.
roll..............................  dynamometer roll.
s.................................  settling.
s.................................  slip.
s.................................  stabilized.
sat...............................  saturated condition.
SC03..............................  air conditioning driving schedule.
span..............................  span quantity.
sda...............................  secondary dilution air.
std...............................  standard conditions.
T.................................  target.
t.................................  throat.
test..............................  test quantity.
uncor.............................  uncorrected quantity.
w.................................  weighted.
zero..............................  zero quantity.
------------------------------------------------------------------------

    (e) Other acronyms and abbreviations. This part uses the following 
additional abbreviations and acronyms:

      Table 5 of Sec.   1066.1005--Other Acronyms and Abbreviations
------------------------------------------------------------------------
                  Acronym                              Meaning
------------------------------------------------------------------------
A/C.......................................  air conditioning.
AC17......................................  air conditioning 2017 test
                                             interval.
ALVW......................................  adjusted loaded vehicle
                                             weight.
ASME......................................  American Society of
                                             Mechanical Engineers.
CFR.......................................  Code of Federal Regulations.
CFV.......................................  critical-flow venturi.
CNG.......................................  compressed natural gas.
CVS.......................................  constant-volume sampler.
EPA.......................................  Environmental Protection
                                             Agency.
ETW.......................................  equivalent test weight.
EV........................................  electric vehicle.
FID.......................................  flame-ionization detector.
FTP.......................................  Federal test procedure.
GC........................................  gas chromatograph.
GEM.......................................  greenhouse gas emissions
                                             model.
GHG.......................................  greenhouse gas (including
                                             CO2, N2O, and CH4).
GPS.......................................  global positioning system.
GVWR......................................  gross vehicle weight rating.
HEV.......................................  hybrid electric vehicle,
                                             including plug-in hybrid
                                             electric vehicles.
HFET......................................  highway fuel economy test.
HLDT......................................  heavy light-duty truck.
HPLC......................................  high pressure liquid
                                             chromatography.
IBR.......................................  incorporated by reference.
LA-92.....................................  Los Angeles 1992 driving
                                             schedule.
MDPV......................................  medium-duty passenger
                                             vehicle.
NIST......................................  National Institute for
                                             Standards and Technology.
NMC.......................................  nonmethane cutter.
PDP.......................................  positive-displacement pump.
PHEV......................................  plug-in hybrid electric
                                             vehicle.
PM........................................  particulate matter.
RESS......................................  rechargeable energy storage
                                             system.
ppm.......................................  parts per million.
SAE.......................................  Society of Automotive
                                             Engineers.
SC03......................................  air conditioning driving
                                             schedule.
SEA.......................................  selective enforcement audit.
SFTP......................................  Supplemental Federal Test
                                             Procedure.
SI........................................  International System of
                                             Units.
SSV.......................................  subsonic venturi.
UDDS......................................  urban dynamometer driving
                                             schedule.
US06......................................  aggressive driving schedule.
U.S.C.....................................  United States Code.
WWV.......................................  NIST radio station call
                                             sign.
------------------------------------------------------------------------

    (f) Densities of chemical species. This part uses the following 
densities of chemical species:

                           Table 6 of Sec.   1066.1005--Densities of Chemical Species
----------------------------------------------------------------------------------------------------------------
                    Symbol                                Quantity a b                 g/m3            g/ft3
----------------------------------------------------------------------------------------------------------------
[rho]CH4......................................  density of methane..............         666.905         18.8847
[rho]CH3OH....................................  density of methanol.............         1332.02         37.7185
[rho]C2H5OH...................................  C1-equivalent density of ethanol         957.559         27.1151
[rho]C2H4O....................................  C1-equivalent density of                 915.658         25.9285
                                                 acetaldehyde.
[rho]C3H8.....................................  density of propane..............         611.035         17.3026
[rho]C3H7OH...................................  C1-equivalent density of                  832.74         23.5806
                                                 propanol.
[rho]CO.......................................  density of carbon monoxide......         1164.41         32.9725
[rho]CO2......................................  density of carbon dioxide.......         1829.53         51.8064
[rho]HC-gas...................................  effective density of                     (see 3)         (see 3)
                                                 hydrocarbon--gaseous fuel c.
[rho]CH2O.....................................  density of formaldehyde.........         1248.21         35.3455
[rho]HC-liq...................................  effective density of                     576.816         16.3336
                                                 hydrocarbon--liquid fueld.

[[Page 432]]

 
[rho]NMHC-gas.................................  effective density of nonmethane          (see 3)         (see 3)
                                                 hydrocarbon--gaseous fuel c.
[rho]NMHC-liq.................................  effective density of nonmethane          576.816         16.3336
                                                 hydrocarbon--liquid fuel d.
[rho]NMHCE-gas................................  effective density of nonmethane          (see 3)         (see 3)
                                                 equivalent hydrocarbon--gaseous
                                                 fuel c.
[rho]NMHCE-liq................................  effective density of nonmethane          576.816         16.3336
                                                 equivalent hydrocarbon--liquid
                                                 fuel d.
[rho]NOx......................................  effective density of oxides of            1912.5          54.156
                                                 nitrogen e.
[rho]N2O......................................  density of nitrous oxide........         1829.66         51.8103
[rho]THC-liq..................................  effective density of total               576.816         16.3336
                                                 hydrocarbon--liquid fuel d.
[rho]THCE-liq.................................  effective density of total               576.816         16.3336
                                                 equivalent hydrocarbon--liquid
                                                 fuel d.
----------------------------------------------------------------------------------------------------------------
a Densities are given at 20 [deg]C and 101.325 kPa.
b Densities for all hydrocarbon containing quantities are given in g/m3-carbon atom and g/ft3-carbon atom.
c The effective density for natural gas fuel and liquefied petroleum gas fuel are defined by an atomic hydrogen-
  to-carbon ratio, [alpha], of the hydrocarbon components of the test fuel. [rho]HCgas = 41.57[middot](12.011 +
  ([alpha][middot]1.008)).
d The effective density for gasoline and diesel fuel are defined by an atomic hydrogen-to-carbon ratio, [alpha],
  of 1.85.
e The effective density of NOX is defined by the molar mass of nitrogen dioxide, NO2.

    (g) Constants. (1) This part uses the following constants for the 
composition of dry air:

   Table 7 to Paragraph (g)(1) of Sec.   1066.1005--Constants for the
                         Composition of Dry Air
------------------------------------------------------------------------
           Symbol                    Quantity               mol/mol
------------------------------------------------------------------------
xArair.....................  amount of argon in dry              0.00934
                              air.
xCO2air....................  amount of carbon                   0.000375
                              dioxide in dry air.
xN2air.....................  amount of nitrogen in               0.78084
                              dry air.
xO2air.....................  amount of oxygen in dry            0.209445
                              air.
------------------------------------------------------------------------

    (2) This part uses the following molar masses or effective molar 
masses of chemical species:

    Table 8 to Paragraph (g)(2) of Sec.   1066.1005--Molar Masses or
               Effective Molar Masses of Chemical Species
------------------------------------------------------------------------
                                                      g/mol  (10-
         Symbol                Quantity        \3\[middot]kg[middot]mol-
                                                          \1\)
------------------------------------------------------------------------
Mair...................  molar mass of dry                   28.96559
                          air \1\.
MH2O...................  molar mass of water.                18.01528
------------------------------------------------------------------------
\1\ See paragraph (g)(1) of this section for the composition of dry air.

    (3) This part uses the following molar gas constant for ideal gases:

 Table 9 to Paragraph (g)(3) of Sec.   1066.1005--Molar Gas Constant for
                               Ideal Gases
------------------------------------------------------------------------
                                                    J/(mol[middot]K)
                                               (m\2\[middot]kg[middot]s-
         Symbol                Quantity             \2\[middot]mol-
                                                   \1\[middot]K-\1\)
------------------------------------------------------------------------
R......................  molar gas constant..                8.314472
------------------------------------------------------------------------

    (h) Prefixes. This part uses the following prefixes to define a 
quantity:

   Table 10 to Paragraph (h) of Sec.   1066.1005--Prefixes to Define a
                                Quantity
------------------------------------------------------------------------
              Symbol                      Quantity             Value
------------------------------------------------------------------------
n.................................  nano................          10-\9\
[micro]...........................  micro...............          10-\6\
m.................................  milli...............          10-\3\
c.................................  centi...............          10-\2\
k.................................  kilo................           10\3\
M.................................  mega................           10\6\
------------------------------------------------------------------------


[79 FR 23823, Apr. 28, 2014, as amended at 80 FR 9124, Feb. 19, 2015; 81 
FR 74215, Oct. 25, 2016; 86 FR 34585, June 29, 2021; 87 FR 64866, Oct. 
26, 2022; 88 FR 4710, Jan. 24, 2023]



Sec.  1066.1010  Incorporation by reference.

    Certain material is incorporated by reference into this part with 
the approval of the Director of the Federal Register under 5 U.S.C. 
552(a) and 1 CFR part 51. To enforce any edition

[[Page 433]]

other than that specified in this section, EPA must publish a document 
in the Federal Register and the material must be available to the 
public. All approved incorporation by reference (IBR) material is 
available for inspection at EPA and at the National Archives and Records 
Administration (NARA). Contact EPA at: U.S. EPA, Air and Radiation 
Docket Center, WJC West Building, Room 3334, 1301 Constitution Ave. NW, 
Washington, DC 20004; www.epa.gov/dockets; (202) 202-1744. For 
information on inspecting this material at NARA, visit www.archives.gov/
federal-register /cfr/ibr-locations.html or email 
[email protected]. The material may be obtained from the following 
sources:
    (a) National Institute of Standards and Technology (NIST), 100 
Bureau Drive, Stop 1070, Gaithersburg, MD 20899-1070; (301) 975-6478; 
www.nist.gov.
    (1) NIST Special Publication 811, 2008 Edition, Guide for the Use of 
the International System of Units (SI), Physics Laboratory, March 2008; 
IBR approved for Sec. Sec.  1066.20(a); 1066.1005.
    (2) [Reserved]
    (b) SAE International, 400 Commonwealth Dr., Warrendale, PA 15096-
0001; (877) 606-7323 (U.S. and Canada) or (724) 776-4970 (outside the 
U.S. and Canada); www.sae.org.
    (1) SAE J1263 MAR2010, Road Load Measurement and Dynamometer 
Simulation Using Coastdown Techniques, Revised March 2010, (``SAE 
J1263''); IBR approved for Sec. Sec.  1066.301(b); 1066.305(a); 
1066.310(b).
    (2) SAE J1634 JUL2017, Battery Electric Vehicle Energy Consumption 
and Range Test Procedure, Revised July 2017, (``SAE J1634''); IBR 
approved for Sec.  1066.501(a).
    (3) SAE J1711 JUN2010, Recommended Practice for Measuring the 
Exhaust Emissions and Fuel Economy of Hybrid-Electric Vehicles, 
Including Plug-In Hybrid Vehicles, Revised June 2010, (``SAE J1711''); 
IBR approved for Sec. Sec.  1066.501(a); 1066.1001.
    (4) SAE J2263 DEC2008, Road Load Measurement Using Onboard 
Anemometry and Coastdown Techniques, Revised December 2008; IBR approved 
for Sec. Sec.  1066.301(b); 1066.305; 1066.310(b).
    (5) SAE J2263 MAY2020, (R) Road Load Measurement Using Onboard 
Anemometry and Coastdown Techniques, Revised May 2020, (``SAE J2263''); 
IBR approved for Sec. Sec.  1066.301(b); 1066.305; 1066.310(b).
    (6) SAE J2264 JAN2014, Chassis Dynamometer Simulation of Road Load 
Using Coastdown Techniques, Revised January 2014, (``SAE J2264''); IBR 
approved for Sec.  1066.315.
    (7) SAE J2711 MAY2020, (R) Recommended Practice for Measuring Fuel 
Economy and Emissions of Hybrid-Electric and Conventional Heavy-Duty 
Vehicles, Revised May 2020, (``SAE J2711''); IBR approved for Sec. Sec.  
1066.501(a); 1066.1001.
    (8) SAE J2951 JAN2014, Drive Quality Evaluation for Chassis 
Dynamometer Testing, Revised January 2014, (``SAE J2951''); IBR approved 
for Sec.  1066.425(j).

[88 FR 4711, Jan. 24, 2023]



PART 1068_GENERAL COMPLIANCE PROVISIONS FOR HIGHWAY, STATIONARY, AND NONROAD PROGRAMS--Table of Contents



          Subpart A_Applicability and Miscellaneous Provisions

Sec.
1068.1 Does this part apply to me?
1068.2 How does this part apply for engines and how does it apply for 
          equipment?
1068.5 How must manufacturers apply good engineering judgment?
1068.10 Practices for handling confidential business information.
1068.11 Confidentiality determinations and related procedures.
1068.15 General provisions for EPA decision-making.
1068.20 May EPA enter my facilities for inspections?
1068.25 What information must I give to EPA?
Sec.  1068.27 May EPA conduct testing with my engines/equipment?
1068.30 What definitions apply to this part?
1068.31 Changing the status of nonroad or stationary engines under the 
          definition of ``nonroad engine''.
1068.32 Explanatory terms.
1068.35 Symbols, acronyms, and abbreviations.
1068.40 Special provisions for implementing changes in the regulations 
          in this part.
1068.45 General labeling provisions.
1068.50 Adjustable parameters.

[[Page 434]]

1068.95 What materials does this part reference?

          Subpart B_Prohibited Actions and Related Requirements

1068.101 What general actions does this regulation prohibit?
1068.103 Provisions related to the duration and applicability of 
          certificates of conformity.
1068.105 What other provisions apply to me specifically if I manufacture 
          equipment needing certified engines?
1068.110 Other provisions for engines/equipment in service.
1068.115 What are manufacturers' emission-related warranty requirements?
1068.120 Requirements for rebuilding engines.
1068.125 What happens if I violate the regulations?

                   Subpart C_Exemptions and Exclusions

1068.201 General exemption and exclusion provisions.
1068.210 Exempting text engines/equipment.
1068.215 Exempting manufacturer-owned engines/equipment.
1068.220 Exempting display engines/equipment.
1068.225 Exempting engines/equipment for national security.
1068.230 Exempting engines/equipment for export.
1068.235 Exempting nonroad engines/equipment used solely for 
          competition.
1068.240 Exempting new replacement engines.
1068.245 Temporary provisions addressing hardship due to unusual 
          circumstances.
1068.250 Extending compliance deadlines for small businesses under 
          hardship.
1068.255 Exempting engines and fuel-system components for hardship for 
          equipment manufacturers and secondary engine manufacturers.
1068.260 General provisions for selling or shipping engines that are not 
          yet in their certified configuration.
1068.261 Delegated assembly and other provisions related to engines not 
          yet in the certified configuration.
1068.262 Shipment of engines to secondary engine manufacturers.
1068.265 Provisions for engines/equipment conditionally exempted from 
          certification.

                            Subpart D_Imports

1068.301 General provisions for importing engines/equipment.
1068.305 How do I get an exemption or exclusion for imported engines/
          equipment?
1068.310 Exclusions for imported engines/equipment.
1068.315 Permanent exemptions for imported engines/equipment.
1068.325 Temporary exemptions for imported engines/equipment.
1068.335 Penalties for violations.
1068.360 Restrictions for assigning a model year to imported engines and 
          equipment.

                Subpart E_Selective Enforcement Auditing

1068.401 What is a selective enforcement audit?
1068.405 What is in a test order?
1068.410 How must I select and prepare my engines/equipment?
1068.415 How do I test my engines/equipment?
1068.420 How do I know when my engine family fails an SEA?
1068.425 What happens if one of my production-line engines/equipment 
          exceeds the emission standards?
1068.430 What happens if a family fails an SEA?
1068.435 May I sell engines/equipment from a family with a suspended 
          certificate of conformity?
1068.440 How do I ask EPA to reinstate my suspended certificate?
1068.445 When may EPA revoke my certificate under this subpart and how 
          may I sell these engines/equipment again?
1068.450 What records must I send to EPA?
1068.455 What records must I keep?

Appendix A to Subpart E of Part 1068--Plans for Selective Enforcement 
          Auditing

       Subpart F_Reporting Defects and Recalling Engines/Equipment

1068.501 How do I report emission-related defects?
1068.505 How does the recall program work?
1068.510 How do I prepare and apply my remedial plan?
1068.515 How do I mark or label repaired engines/equipment?
1068.520 How do I notify affected owners?
1068.525 What records must I send to EPA?
1068.530 What records must I keep?
1068.535 How can I do a voluntary recall for emission-related problems?

                           Subpart G_Hearings

1068.601 Overview.
1068.610 Request for hearing--suspending, revoking, or voiding a 
          certificate of conformity.
1068.615 Request for hearing--denied application for certification, 
          automatically suspended certificate, and determinations 
          related to certification.
1068.620 Request for hearing--recall.
1068.625 Request for hearing--nonconformance penalties.

[[Page 435]]

1068.630 Request for hearing--allowable maintenance.
1068.650 Procedures for informal hearings.

Appendix A to Part 1068--Emission-Related Components
Appendix B to Part 1068--Emission-Related Parameters and Specifications
Appendix C to Part 1068--High-Altitude Counties

    Authority: 42 U.S.C. 7401-7671q.

    Source: 73 FR 59344, Oct. 8, 2008, unless otherwise noted.



          Subpart A_Applicability and Miscellaneous Provisions



Sec.  1068.1  Does this part apply to me?

    (a) The provisions of this part apply to everyone with respect to 
the engine and equipment categories as described in this paragraph (a). 
The provisions of this part apply to everyone, including owners, 
operators, parts manufacturers, and persons performing maintenance. 
Where we identify an engine category, the provisions of this part also 
apply with respect to the equipment using such engines. This part 
applies to different engine and equipment categories as follows:
    (1) This part applies to motor vehicles we regulate under 40 CFR 
part 86, subpart S, to the extent and in the manner specified in 40 CFR 
parts 85 and 86.
    (2) This part 1068 applies for heavy-duty motor vehicles and motor 
vehicle engines we regulate under 40 CFR parts 1036 and 1037. This 
includes trailers. This part 1068 applies to heavy-duty motor vehicles 
and motor vehicle engines certified under 40 CFR part 86 to the extent 
and in the manner specified in 40 CFR parts 85, 86, and 1036.
    (3) This part applies to highway motorcycles we regulate under 40 
CFR part 86, subparts E and F, to the extent and in the manner specified 
in 40 CFR parts 85 and 86.
    (4) This part applies to aircraft and aircraft engines we regulate 
under 40 CFR parts 1030 and 1031 to the extent and in the manner 
specified in 40 CFR parts 1030 and 1031.
    (5) This part 1068 applies for locomotives that are subject to the 
provisions of 40 CFR part 1033.
    (6) This part 1068 applies for land-based nonroad compression-
ignition engines that are subject to the provisions of 40 CFR part 1039. 
This part 1068 applies for engines certified under 40 CFR part 89 to the 
extent and in the manner specified in 40 CFR part 1039.
    (7) This part applies for stationary compression-ignition engines 
certified using the provisions of 40 CFR parts 1039 and 1042 as 
described in 40 CFR part 60, subpart IIII.
    (8) This part 1068 applies for marine compression-ignition engines 
that are subject to the provisions of 40 CFR part 1042. This part 1068 
applies for marine compression-ignition engines certified under 40 CFR 
part 94 to the extent and in the manner specified in 40 CFR part 1042.
    (9) This part 1068 applies for marine spark-ignition engines that 
are subject to the provisions of 40 CFR part 1045. This part 1068 
applies for marine spark-ignition engines certified under 40 CFR part 91 
to the extent and in the manner specified in 40 CFR part 1045.
    (10) This part applies for large nonroad spark-ignition engines that 
are subject to the provisions of 40 CFR part 1048.
    (11) This part applies for stationary spark-ignition engines 
certified using the provisions of 40 CFR part 1048 or 1054, as described 
in 40 CFR part 60, subpart JJJJ.
    (12) This part applies for recreational engines and vehicles, 
including snowmobiles, off-highway motorcycles, and all-terrain vehicles 
that are subject to the provisions of 40 CFR part 1051.
    (13) This part applies for small nonroad spark-ignition engines that 
are subject to the provisions of 40 CFR part 1054. This part 1068 
applies for nonroad spark-ignition engines certified under 40 CFR part 
90 to the extent and in the manner specified in 40 CFR part 1054.
    (14) This part applies for fuel-system components installed in 
nonroad equipment powered by volatile liquid fuels that are subject to 
the provisions of 40 CFR part 1060.
    (15) This part 1068 applies to portable fuel containers we regulate 
under 40 CFR part 59 to the extent and in the manner specified in 40 CFR 
part 59, subpart F.
    (b) [Reserved]

[[Page 436]]

    (c) Paragraph (a) of this section identifies the parts of the CFR 
that define emission standards and other requirements for particular 
types of engines and equipment. This part 1068 refers to each of these 
other parts generically as the ``standard-setting part.'' For example, 
40 CFR part 1051 is always the standard-setting part for snowmobiles. 
Follow the provisions of the standard-setting part if they are different 
than any of the provisions in this part.
    (d) Specific provisions in this part 1068 start to apply separate 
from the schedule for certifying engines/equipment to new emission 
standards, as follows:
    (1) The provisions of Sec. Sec.  1068.30 and 1068.310 apply for 
stationary spark-ignition engines built on or after January 1, 2004, and 
for stationary compression-ignition engines built on or after January 1, 
2006.
    (2) [Reserved]
    (3) The standard-setting part may specify how the provisions of this 
part 1068 apply for uncertified engines/equipment.

[81 FR 74217, Oct. 25, 2016, as amended at 86 FR 34588, June 29, 2021; 
88 FR 4712, Jan. 24, 2023]



Sec.  1068.2  How does this part apply for engines and how
does it apply for equipment?

    (a) See the standard-setting part to determine if engine-based and/
or equipment-based standards apply. (Note: Some equipment is subject to 
engine-based standards for exhaust emission and equipment-based 
standards for evaporative emissions.)
    (b) The provisions of this part apply differently depending on 
whether the engine or equipment is required to be certified.
    (1) Subpart A and subpart B of this part apply to engines and 
equipment, without regard to which is subject to certification 
requirements in the standard-setting part.
    (2) Subparts C, D, and E of this part apply to the engines or to the 
equipment, whichever is subject to certification requirements in the 
standard-setting part.
    (3) Subpart F of this part generally applies to the engines or to 
the equipment, whichever is subject to standards under the standard-
setting part. However, since subpart F of this part addresses in-use 
engines and equipment (in which the engine is installed in the 
equipment), the requirements do not always distinguish between engines 
and equipment.
    (c) For issues related to testing, read the term ``engines/
equipment'' to mean engines for engines subject to engine-based testing 
and equipment for equipment subject to equipment-based testing; 
otherwise, read the term ``engines/equipment'' to mean engines for 
sources subject to engine-based standards and equipment for sources 
subject to equipment-based standards.
    (d) When we use the term engines (rather than engines/equipment), 
read it to mean engines without regard to whether the source is subject 
to engine-based standards or testing. When we use the term equipment 
(rather than engines/equipment), read it to mean equipment without 
regard to whether the source is subject to equipment-based standards or 
testing. (Note: The definition of ``equipment'' in Sec.  1068.30 
includes the engine.)
    (e) The terminology convention described in this section is not 
intended to limit our authority or your obligations under the Clean Air 
Act.



Sec.  1068.5  How must manufacturers apply good engineering judgment?

    (a) You must use good engineering judgment for decisions related to 
any requirements under this chapter. This includes your applications for 
certification, any testing you do to show that your certification, 
production-line, and in-use engines/equipment comply with requirements 
that apply to them, and how you select, categorize, determine, and apply 
these requirements.
    (b) If we send you a written request, you must give us a written 
description of the engineering judgment in question. Respond within 15 
working days of receiving our request unless we allow more time.
    (c) We may reject your decision if it is not based on good 
engineering judgment or is otherwise inconsistent with the requirements 
that apply, based on the following provisions:

[[Page 437]]

    (1) We may suspend, revoke, or void a certificate of conformity if 
we determine you deliberately used incorrect information or overlooked 
important information, that you did not decide in good faith, or that 
your decision was not rational.
    (2) If we believe a different decision would better reflect good 
engineering judgment, but none of the provisions of paragraph (c)(1) of 
this section apply, we will tell you of our concern (and its basis). You 
will have 30 days to respond to our concerns, or more time if we agree 
that you need it to generate more information. After considering your 
information, we will give you a final ruling. If we conclude that you 
did not use good engineering judgment, we may reject your decision and 
apply the new ruling to similar situations as soon as possible.
    (d) We will tell you in writing of the conclusions we reach under 
paragraph (c) of this section and explain our reasons for them.
    (e) If you disagree with our conclusions, you may file a request for 
a hearing with the Designated Compliance Officer as described in subpart 
G of this part. In your request, specify your objections, include data 
or supporting analysis, and get your authorized representative's 
signature. If we agree that your request raises a substantial factual 
issue, we will hold the hearing according to subpart F of this part.



Sec.  1068.10  Practices for handling confidential business information.

    The provisions of this section apply both to any information you 
send us and to any information we collect from inspections, audits, or 
other site visits.
    (a) When you submit information to us, if you claim any of that 
information as confidential, you may identify what you claim to be 
confidential by marking, circling, bracketing, stamping, or some other 
method; however, we will not consider any claims of confidentiality over 
information we have determined to be not entitled to confidential 
treatment under Sec.  1068.11 or other applicable provisions.
    (b) If you send us information without claiming it is confidential, 
we may make it available to the public without further notice to you, as 
described in 40 CFR 2.301(j).
    (c) For submissions that include information that may be entitled to 
confidential treatment, we may require that you send a ``public'' copy 
of the report that does not include the confidential information. We may 
require that you substantiate your claim to confidential treatment for 
any items not contained in the public version. We will release 
additional information from the complete version of such a submission 
only as allowed under 40 CFR 2.301(j) and as described in this subpart 
and the standard-setting part.
    (d) We will safeguard your confidential business information (CBI) 
as described in 40 CFR 2.301(j). Also, we will treat certain information 
as confidential and will only disclose this information if it has been 
determined to be not entitled to confidential treatment as specified in 
Sec.  1068.11(c). The following general provisions describe how we will 
process requests for making information publicly available:
    (1) Certification information. We will treat information submitted 
in an application for certification as confidential until the 
introduction-into-commerce date you identify in your application for 
certification consistent with 40 CFR 2.301(a)(2)(ii)(B). If you do not 
identify an introduction-into-commerce date or if we issue the 
certificate after your specified date, we will treat information 
submitted in an application for certification as described in Sec.  
1068.11 after the date we issue the certificate.
    (2) Preliminary and superseded information. Preliminary and 
superseded versions of information you submit are covered by 
confidentiality determinations in the same manner as final documents. 
However, we will generally not disclose preliminary or superseded 
information unless we receive a request under 5 U.S.C. 552 that 
specifically asks for all versions of a document, including preliminary 
and superseded versions. We will consider a document preliminary if we 
have not reviewed it to verify its accuracy or if the reporting deadline 
has not yet passed. We will consider information superseded if

[[Page 438]]

you submit a new document or a revised application for certification to 
replace the earlier version.
    (3) Authorizing CBI disclosure. The provisions of this section do 
not prevent us from disclosing protected information if you specifically 
authorize it.
    (4) Relationship to the standard-setting part. The standard-setting 
part may identify additional provisions related to confidentiality 
determinations. Note that the standard-setting part identifies 
information requirements that apply for each type of engine/equipment. 
If this section identifies information that is not required for a given 
engine, that does not create a requirement to submit the information.
    (5) Changes in law. The confidentiality determinations in this 
section and in the standard-setting parts may be changed through the 
processes described in 40 CFR 2.301(j)(4).

[88 FR 4712, Jan. 24, 2023]



Sec.  1068.11  Confidentiality determinations and related procedures.

    This section characterizes various categories of information for 
purposes of making confidentiality determinations, as follows:
    (a) This paragraph (a) applies the definition of ``Emission data'' 
in 40 CFR 2.301(a) for information related to engines/equipment subject 
to this part. ``Emission data'' cannot be treated as confidential 
business information and shall be available to be disclosed to the 
public except as specified in Sec.  1068.10(d)(1). The following 
categories of information qualify as emission data, except as specified 
in paragraph (c) of this section:
    (1) Certification and compliance information, including information 
submitted in an application for a certificate of conformity that is used 
to assess compliance.
    (2) Fleet value information, including information submitted for 
compliance with fleet average emission standards and emissions related 
ABT credit information, including the information used to generate 
credits.
    (3) Source family information. For example, engine family 
information or test group information would identify the regulated 
emission source.
    (4) Test information and results, including emission test results 
and other data from emission testing that are submitted in an 
application for a certificate of conformity, test results from in-use 
testing, production-line testing, and any other testing to demonstrate 
emissions. The information in this category includes all related 
information to characterize test results, document the measurement 
procedure, and modeling inputs and outputs where the compliance 
demonstration is based on computer modeling.
    (5) ABT credit information, including information submitted for 
current and future compliance demonstrations using credits under an ABT 
program.
    (6) Production volume, including information submitted for 
compliance with fleet average emission standards, compliance with 
requirements to test production engines/equipment, or compliance through 
ABT programs.
    (7) Defect and recall information, including all information 
submitted in relation to a defect or recall except the remedial steps 
you identify in Sec.  1068.510(a)(2).
    (8) Selective enforcement audit compliance information.
    (b) The following categories of information are not eligible for 
confidential treatment, except as specified in Sec.  1068.10(d)(1):
    (1) Published information, including information that is made 
available in annual and quarterly filings submitted to the U.S. 
Securities and Exchanges Commission, on company websites, or otherwise 
made publicly available by the information submitter.
    (2) Observable information available to the public after the 
introduction to commerce date.
    (c) The following categories of information are subject to the 
process for confidentiality determinations in 40 CFR part 2 as described 
in 40 CFR 2.301(j)(5):
    (1) Projected sales volume and projected production volume.
    (2) Production start and end dates.
    (3) Detailed description of emission control operation and function.
    (4) Design specifications related to aftertreatment devices.
    (5) Description of auxiliary emission control devices (AECDs).

[[Page 439]]

    (6) Plans for meeting regulatory requirements. For example, this 
applies for any projections of emission credits for the coming model 
year or determinations of the number of required repair facilities that 
are based on projected production volumes.
    (7) The following information related to deterioration factors and 
other adjustment factors:
    (i) Procedures to determine deterioration factors and other emission 
adjustment factors.
    (ii) Any information used to justify those procedures.
    (iii) Emission measurements you use to compare procedures or 
demonstrate that the procedures are appropriate.
    (8) Financial information related to the following items:
    (i) ABT credit transactions, including dollar amount, identity of 
parties, and contract information.
    (ii) Meeting bond requirements, including aggregate U.S. asset 
holdings, financial details regarding specific assets, whether the 
manufacturer or importer obtains a bond, and copies of bond policies.
    (9) Serial numbers or other information to identify specific engines 
or equipment selected for testing.
    (10) Procedures that apply based on your request to test engines/
equipment differently than we specify in the regulation. This applies 
for special and alternative test procedures. This also applies, for 
example, if we approve a broader or narrower zone of engine operation 
for not-to-exceed testing.
    (11) Information related to testing vanadium catalysts in 40 CFR 
part 1065, subpart L.
    (12) GPS data identifying the location for in-use emission 
measurements.
    (13) Information related to possible defects that are subject to 
further investigation (not confirmed defects).
    (14) Information submitted in support of a requested exemption.
    (d) If you submit information that is not addressed in paragraphs 
(a) through (c) of this section, you may claim the information as 
confidential. We may require you to provide us with information to 
substantiate your claims. If claimed, we may consider this 
substantiating information to be confidential to the same degree as the 
information for which you are requesting confidential treatment. We will 
make our determination based on your statements to us, the supporting 
information you send us, and any other available information. However, 
we may determine that your information is not subject to confidential 
treatment consistent with 40 CFR part 2 and 5 U.S.C. 552(b)(4).
    (e) Applications for certification and submitted reports typically 
rely on software or templates to identify specific categories of 
information. If you submit information in a comment field designated for 
users to add general information, we will respond to requests for 
disclosing that information consistent with paragraphs (a) through (d) 
of this section.

[88 FR 4713, Jan. 24, 2023]



Sec.  1068.15  General provisions for EPA decision-making.

    (a) Not all EPA employees may represent the Agency with respect to 
EPA decisions under this part or the standard-setting part. Only the 
Administrator of the Environmental Protection Agency or an official to 
whom the Administrator has delegated specific authority may represent 
the Agency. For more information, ask for a copy of the relevant 
sections of the EPA Delegations Manual from the Designated Compliance 
Officer.
    (b) The regulations in this part and in the standard-setting part 
have specific requirements describing how to get EPA approval before you 
take specific actions. These regulations also allow us to waive some 
specific requirements. For provisions or flexibilities that we address 
frequently, we may choose to provide detailed guidance in supplemental 
compliance instructions for manufacturers. Such instructions will 
generally state how they relate to the need for pre-approval. Unless we 
explicitly state so, you should not consider full compliance with the 
instructions to be equivalent to EPA approval.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74217, Oct. 25, 2016]

[[Page 440]]



Sec.  1068.20  May EPA enter my facilities for inspections?

    (a) We may inspect your testing, manufacturing processes, storage 
facilities (including port facilities for imported engines and equipment 
or other relevant facilities), or records, as authorized by the Clean 
Air Act, to enforce the provisions of this chapter. Inspectors will have 
authorizing credentials and will limit inspections to reasonable times--
usually, normal operating hours.
    (b) We may select any facility to do any of the following:
    (1) Inspect and monitor any aspect of engine or equipment 
manufacturing, assembly, storage, or other procedures, and any 
facilities where you do them.
    (2) Inspect and monitor any aspect of engine or equipment test 
procedures or test-related activities, including test engine/equipment 
selection, preparation, service accumulation, emission duty cycles, and 
maintenance and verification of your test equipment's calibration.
    (3) Inspect and copy records or documents related to assembling, 
storing, selecting, and testing an engine or piece of equipment.
    (4) Inspect and photograph any part or aspect of engines or 
equipment and components you use for assembly.
    (c) You must give us reasonable help without charge during an 
inspection authorized by the Clean Air Act. For example, you may need to 
help us arrange an inspection with the facility's managers, including 
clerical support, copying, and translation. You may also need to show us 
how the facility operates and answer other questions. If we ask in 
writing to see a particular employee at the inspection, you must ensure 
that he or she is present (legal counsel may accompany the employee).
    (d) If you have facilities in other countries, we expect you to 
locate them in places where local law does not keep us from inspecting 
as described in this section. We will not try to inspect if we learn 
that local law prohibits it, but we may suspend your certificate if we 
are not allowed to inspect.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74217, Oct. 25, 2016]



Sec.  1068.25  What information must I give to EPA?

    If you are subject to the requirements of this part, we may require 
you to give us information to evaluate your compliance with any 
regulations that apply, as authorized by the Clean Air Act. This 
includes the following things:
    (a) You must provide the information we require in this chapter. We 
may require an authorized representative of your company to approve and 
sign any submission of information to us, and to certify that the 
information is accurate and complete.
    (b) You must establish and maintain records, perform tests, make 
reports and provide additional information that we may reasonably 
require under section 208 of the Clean Air Act (42 U.S.C. 7542). This 
also applies to engines/equipment we exempt from emission standards or 
prohibited acts. Unless we specify otherwise, you must keep required 
records for eight years.
    (c) You are responsible for statements and information in your 
applications for certification or any other requests or reports. If you 
provide statements or information to someone for submission to EPA, you 
are responsible for these statements and information as if you had 
submitted them to EPA yourself. For example, knowingly submitting false 
information to someone else for inclusion in an application for 
certification would be deemed to be a submission of false information to 
the U.S. government in violation of 18 U.S.C. 1001.

[73 FR 59344, Oct. 8, 2008, as amended at 75 FR 23058, Apr. 30, 2010]



Sec.  1068.27  May EPA conduct testing with my engines/equipment?

    (a) As described in the standard-setting part, we may perform 
testing on your engines/equipment before we issue a certificate of 
conformity. This is generally known as confirmatory testing.
    (b) If we request it, you must make a reasonable number of 
production-line engines or pieces of production-line equipment available 
for a reasonable time so we can test or inspect them for compliance with 
the requirements of this chapter.

[[Page 441]]

    (c) If your emission-data engine/equipment or production engine/
equipment requires special components for proper testing, you must 
promptly provide any such components to us if we ask for them.

[81 FR 74217, Oct. 25, 2016]



Sec.  1068.30  Definitions.

    The following definitions apply to this part. The definitions apply 
to all subparts unless we note otherwise. All undefined terms have the 
meaning the Clean Air Act gives to them. The definitions follow:
    Affiliated companies or affiliates means one of the following:
    (1) For determinations related to small manufacturer allowances or 
other small business provisions, these terms mean all entities 
considered to be affiliates with your entity under the Small Business 
Administration's regulations in 13 CFR 121.103.
    (2) For all other provisions, these terms mean all of the following:
    (i) Parent companies (as defined in this section).
    (ii) Subsidiaries (as defined in this section).
    (iii) Subsidiaries of your parent company.
    Aftertreatment means relating to a catalytic converter, particulate 
filter, or any other system, component, or technology mounted downstream 
of the exhaust valve (or exhaust port) whose design function is to 
reduce emissions in the engine exhaust before it is exhausted to the 
environment. Exhaust gas recirculation (EGR) is not aftertreatment.
    Aircraft means any vehicle capable of sustained air travel more than 
100 feet above the ground.
    Certificate holder means a manufacturer (including importers) with a 
valid certificate of conformity for at least one family in a given model 
year, or the preceding model year. Note that only manufacturers may hold 
certificates. Your applying for or accepting a certificate is deemed to 
be your agreement that you are a manufacturer.
    Clean Air Act means the Clean Air Act, as amended, 42 U.S.C. 7401- 
7671q.
    Critical emission-related component means a part or system whose 
primary purpose is to reduce emissions or whose failure would commonly 
increase emissions without significantly degrading engine/equipment 
performance.
    Date of manufacture means one of the following:
    (1) For engines, the date on which the crankshaft is installed in an 
engine block, with the following exceptions:
    (i) For engines produced by secondary engine manufacturers under 
Sec.  1068.262, date of manufacture means the date the engine is 
received from the original engine manufacturer. You may assign an 
earlier date up to 30 days before you received the engine, but not 
before the crankshaft was installed. You may not assign an earlier date 
if you cannot demonstrate the date the crankshaft was installed.
    (ii) Manufacturers may assign a date of manufacture at a point in 
the assembly process later than the date otherwise specified under this 
definition. For example, a manufacturer may use the build date printed 
on the label or stamped on the engine as the date of manufacture.
    (2) For equipment, the date on which the engine is installed, unless 
otherwise specified in the standard-setting part. Manufacturers may 
alternatively assign a date of manufacture later in the assembly 
process.
    Days means calendar days, including weekends and holidays.
    Defeat device has the meaning given in the standard-setting part.
    Designated Compliance Officer means one of the following:
    (1) For motor vehicles regulated under 40 CFR part 86, subpart S: 
Director, Light-Duty Vehicle Center, U.S. Environmental Protection 
Agency, 2000 Traverwood Drive, Ann Arbor, MI 48105; 
[email protected]; www.epa.gov/ve-certification.
    (2) For compression-ignition engines used in heavy-duty highway 
vehicles regulated under 40 CFR part 86, subpart A, and 40 CFR parts 
1036 and 1037, and for nonroad and stationary compression-ignition 
engines or equipment regulated under 40 CFR parts 60, 1033, 1039, and 
1042: Director, Diesel Engine Compliance Center, U.S. Environmental 
Protection Agency, 2000 Traverwood Drive, Ann Arbor, MI 48105; 
[email protected]; www.epa.gov/ve-certification.

[[Page 442]]

    (3) Director, Gasoline Engine Compliance Center, U.S. Environmental 
Protection Agency, 2000 Traverwood Drive, Ann Arbor, MI 48105; 
[email protected]; www.epa.gov/ve-certification, for all the 
following engines and vehicles:
    (i) For spark-ignition engines used in heavy-duty highway vehicles 
regulated under 40 CFR part 86, subpart A, and 40 CFR parts 1036 and 
1037,
    (ii) For highway motorcycles regulated under 40 CFR part 86, subpart 
E.
    (iii) For nonroad and stationary spark-ignition engines or equipment 
regulated under 40 CFR parts 60, 1045, 1048, 1051, 1054, and 1060.
    Engine means an engine block with an installed crankshaft, or a gas 
turbine engine. The term engine does not include engine blocks without 
an installed crankshaft, nor does it include any assembly of 
reciprocating engine components that does not include the engine block. 
(Note: For purposes of this definition, any component that is the 
primary means of converting an engine's energy into usable work is 
considered a crankshaft, whether or not it is known commercially as a 
crankshaft.) This includes complete and partially complete engines as 
follows:
    (1) A complete engine is a fully assembled engine in its final 
configuration. In the case of equipment-based standards, an engine is 
not considered complete until it is installed in the equipment, even if 
the engine itself is fully assembled.
    (2) A partially complete engine is an engine that is not fully 
assembled or is not in its final configuration. Except where we specify 
otherwise in this part or the standard-setting part, partially complete 
engines are subject to the same standards and requirements as complete 
engines. The following would be considered examples of partially 
complete engines:
    (i) An engine that is missing certain emission-related components.
    (ii) A new engine that was originally assembled as a motor-vehicle 
engine that will be recalibrated for use as a nonroad engine.
    (iii) A new engine that was originally assembled as a land-based 
engine that will be modified for use as a marine propulsion engine.
    (iv) A short block consisting of a crankshaft and other engine 
components connected to the engine block, but missing the head assembly.
    (v) A long block consisting of all engine components except the fuel 
system and an intake manifold.
    (vi) In the case of equipment-based standards, a fully functioning 
engine that is not yet installed in the equipment. For example, a fully 
functioning engine that will be installed in an off-highway motorcycle 
or a locomotive is considered partially complete until it is installed 
in the equipment.
    Engine-based standard means an emission standard expressed in units 
of grams of pollutant per kilowatt-hour (or grams of pollutant per 
horsepower-hour) that applies to the engine. Emission standards are 
either engine-based or equipment-based. Note that engines may be subject 
to additional standards such as smoke standards.
    Engine-based test means an emission test intended to measure 
emissions in units of grams of pollutant per kilowatt-hour (or grams of 
pollutant per horsepower-hour), without regard to whether the standard 
applies to the engine or equipment. Note that some products that are 
subject to engine-based testing are subject to additional test 
requirements such as for smoke.
    Engine configuration means a unique combination of engine hardware 
and calibration within an engine family. Engines within a single engine 
configuration differ only with respect to normal production variability 
or factors unrelated to emissions.
    Engine/equipment and engines/equipment mean engine(s) and/or 
equipment depending on the context. Specifically these terms mean the 
following:
    (1) Engine(s) when only engine-based standards apply.
    (2) Engine(s) for testing issues when engine-based testing applies.
    (3) Engine(s) and equipment when both engine-based and equipment-
based standards apply.
    (4) Equipment when only equipment-based standards apply.
    (5) Equipment for testing issues when equipment-based testing 
applies.
    Equipment means one of the following things:

[[Page 443]]

    (1) Any vehicle, vessel, or other type of equipment that is subject 
to the requirements of this part or that uses an engine that is subject 
to the requirements of this part. An installed engine is part of the 
equipment. Motor vehicle trailers are a type of equipment that is 
subject to the requirements of this part.
    (2) Fuel-system components that are subject to an equipment-based 
standard under this chapter. Installed fuel-system components are also 
considered part of the engine/equipment to which they are attached.
    Equipment-based standard means an emission standard that applies to 
the equipment in which an engine is used or to fuel-system components 
associated with an engine, without regard to how the emissions are 
measured. If equipment-based standards apply, we require that the 
equipment or fuel-system components be certified rather than just the 
engine. Emission standards are either engine-based or equipment-based. 
For example, recreational vehicles we regulate under 40 CFR part 1051 
are subject to equipment-based standards even if emission measurements 
are based on engine operation alone.
    Excluded means relating to engines/equipment that are not subject to 
emission standards or other requirements because they do not meet the 
definitions or other regulatory provisions that define applicability. 
For example, a non-stationary engine that is used solely for off-highway 
competition is excluded from the requirements of this part because it 
meets neither the definition of ``motor vehicle engine'' nor ``nonroad 
engine'' under section 216 of the Clean Air Act.
    Exempted means relating to engines/equipment that are subject to 
certain standards or other requirements, but are not required to meet 
those standards or requirements, subject to one or more qualifying 
conditions. Exempted engines/equipment must conform to regulatory 
conditions specified for an exemption in this part 1068 or in the 
standard-setting part. Engines/equipment exempted with respect to a 
certain tier of standards may be required to comply with an earlier tier 
of standards as a condition of the exemption; for example, engines 
exempted with respect to Tier 3 standards may be required to comply with 
Tier 1 or Tier 2 standards.
    Family means engine family or emission family, as applicable, under 
the standard-setting part.
    Final deteriorated test result has the meaning given in the 
standard-setting part. If it is not defined in the standard-setting 
part, it means the emission level that results from applying all 
appropriate adjustments (such as deterioration factors) to the measured 
emission result of the emission-data engine.
    Gas turbine engine means anything commercially known as a gas 
turbine engine or any collection of assembled engine components that is 
substantially similar to engines commercially known as gas turbine 
engines. For example, a jet engine is a gas turbine engine. Gas turbine 
engines may be complete or partially complete. Turbines that rely on 
external combustion such as steam engines are not gas turbine engines.
    Good engineering judgment means judgments made consistent with 
generally accepted scientific and engineering principles and all 
available relevant information. See Sec.  1068.5.
    Manufacturer has the meaning given in section 216(1) of the Clean 
Air Act (42 U.S.C. 7550(1)). In general, this term includes any person 
who manufactures or assembles an engine or piece of equipment for sale 
in the United States or otherwise introduces a new engine or piece of 
equipment into U.S. commerce. This includes importers that import new 
engines or new equipment into the United States for resale. It also 
includes secondary engine manufacturers.
    Model year has the meaning given in the standard-setting part. 
Unless the standard-setting part specifies otherwise, model year for 
individual engines/equipment is based on the date of manufacture or a 
later stage in the assembly process determined by the manufacturer, 
subject to the limitations described in Sec. Sec.  1068.103 and 
1068.360. The model year of a new engine that is neither certified nor 
exempt is deemed to be the calendar year in which it is sold, offered 
for sale, imported, or delivered

[[Page 444]]

or otherwise introduced into U.S. commerce.
    Motor vehicle has the meaning given in 40 CFR 85.1703.
    New has the meaning we give it in the standard-setting part. Note 
that in certain cases, used and remanufactured engines/equipment may be 
``new'' engines/equipment.
    Nonroad engine means:
    (1) Except as discussed in paragraph (2) of this definition, a 
nonroad engine is an internal combustion engine that meets any of the 
following criteria:
    (i) It is (or will be) used in or on a piece of equipment that is 
self-propelled or serves a dual purpose by both propelling itself and 
performing another function (such as garden tractors, off-highway mobile 
cranes and bulldozers).
    (ii) It is (or will be) used in or on a piece of equipment that is 
intended to be propelled while performing its function (such as 
lawnmowers and string trimmers).
    (iii) By itself or in or on a piece of equipment, it is portable or 
transportable, meaning designed to be and capable of being carried or 
moved from one location to another. Indicia of transportability include, 
but are not limited to, wheels, skids, carrying handles, dolly, trailer, 
or platform.
    (2) An internal combustion engine is not a nonroad engine if it 
meets any of the following criteria:
    (i) The engine is used to propel a motor vehicle, an aircraft, or 
equipment used solely for competition.
    (ii) The engine is regulated under 40 CFR part 60, (or otherwise 
regulated by a federal New Source Performance Standard promulgated under 
section 111 of the Clean Air Act (42 U.S.C. 7411)). Note that this 
criterion does not apply for engines meeting any of the criteria of 
paragraph (1) of this definition that are voluntarily certified under 40 
CFR part 60.
    (iii) The engine otherwise included in paragraph (1)(iii) of this 
definition remains or will remain at a location for more than 12 
consecutive months or a shorter period of time for an engine located at 
a seasonal source. A location is any single site at a building, 
structure, facility, or installation. For any engine (or engines) that 
replaces an engine at a location and that is intended to perform the 
same or similar function as the engine replaced, include the time period 
of both engines in calculating the consecutive time period. An engine 
located at a seasonal source is an engine that remains at a seasonal 
source during the full annual operating period of the seasonal source. A 
seasonal source is a stationary source that remains in a single location 
on a permanent basis (i.e., at least two years) and that operates at 
that single location approximately three months (or more) each year. See 
Sec.  1068.31 for provisions that apply if the engine is removed from 
the location.
    Operating hours means:
    (1) For engine and equipment storage areas or facilities, times 
during which people other than custodians and security personnel are at 
work near, and can access, a storage area or facility.
    (2) For other areas or facilities, times during which an assembly 
line operates or any of the following activities occurs:
    (i) Testing, maintenance, or service accumulation.
    (ii) Production or compilation of records.
    (iii) Certification testing.
    (iv) Translation of designs from the test stage to the production 
stage.
    (v) Engine or equipment manufacture or assembly.
    Parent company means any entity that has a controlling ownership of 
another company. Note that the standard-setting part may treat a partial 
owner as a parent company even if it does not have controlling ownership 
of a company.
    Piece of equipment means any vehicle, vessel, locomotive, aircraft, 
or other type of equipment equipped with engines to which this part 
applies.
    Placed into service means used for its intended purpose. Engines/
equipment do not qualify as being ``placed into service'' based on 
incidental use by a manufacturer or dealer.
    Reasonable technical basis means information that would lead a 
person familiar with engine design and function to reasonably believe a 
conclusion related to compliance with the requirements of this part. For 
example, it would be reasonable to believe that

[[Page 445]]

parts performing the same function as the original parts (and to the 
same degree) would control emissions to the same degree as the original 
parts. Note that what is a reasonable basis for a person without 
technical training might not qualify as a reasonable technical basis.
    Relating to as used in this section means relating to something in a 
specific, direct manner. This expression is used in this section only to 
define terms as adjectives and not to broaden the meaning of the terms. 
Note that ``relating to'' is used in the same manner as in the standard-
setting parts.
    Replacement engine means an engine exempted as a replacement engine 
under Sec.  1068.240.
    Revoke means to terminate the certificate or an exemption for a 
family. If we revoke a certificate or exemption, you must apply for a 
new certificate or exemption before continuing to introduce the affected 
engines/equipment into U.S. commerce. This does not apply to engines/
equipment you no longer possess.
    Secondary engine manufacturer means anyone who produces a new engine 
by modifying a complete or partially complete engine that was made by a 
different company. For the purpose of this definition, ``modifying'' 
does not include making changes that do not remove an engine from its 
original certified configuration. Secondary engine manufacturing 
includes, for example, converting automotive engines for use in 
industrial applications, or land-based engines for use in marine 
applications. This applies whether it involves a complete or partially 
complete engine and whether the engine was previously certified to 
emission standards or not.
    (1) Manufacturers controlled by the manufacturer of the base engine 
(or by an entity that also controls the manufacturer of the base engine) 
are not secondary engine manufacturers; rather, both entities are 
considered to be one manufacturer for purposes of this part.
    (2) This definition applies equally to equipment manufacturers that 
modify engines. Also, equipment manufacturers that certify to equipment-
based standards using engines produced by another company are deemed to 
be secondary engine manufacturers.
    (3) Except as specified in paragraph (2) of this definition, 
companies importing complete engines into the United States are not 
secondary engine manufacturers regardless of the procedures and 
relationships between companies for assembling the engines.
    Small business means either of the following:
    (1) A company that qualifies under the standard-setting part for 
special provisions for small businesses or small-volume manufacturers.
    (2) A company that qualifies as a small business under the 
regulations adopted by the Small Business Administration at 13 CFR 
121.201 if the standard-setting part does not establish such qualifying 
criteria.
    Standard-setting part means a part in the Code of Federal 
Regulations that defines emission standards for a particular engine and/
or piece of equipment (see Sec.  1068.1(a)). For example, the standard-
setting part for marine spark-ignition engines is 40 CFR part 1045. For 
provisions related to evaporative emissions, the standard-setting part 
may be 40 CFR part 1060, as specified in 40 CFR 1060.1.
    Subsidiary means an entity that is owned or controlled by a parent 
company.
    Sulfur-sensitive technology means an emission control technology 
that experiences a significant drop in emission control performance or 
emission-system durability when an engine is operated on low-sulfur 
diesel fuel (i.e., fuel with a sulfur concentration of 300 to 500 ppm) 
as compared to when it is operated on ultra low-sulfur diesel fuel 
(i.e., fuel with a sulfur concentration less than 15 ppm). Exhaust gas 
recirculation is not a sulfur-sensitive technology.
    Suspend means to temporarily discontinue the certificate or an 
exemption for a family. If we suspend a certificate, you may not sell, 
offer for sale, or introduce or deliver into commerce in the United 
States or import into the United States engines/equipment from that 
family unless we reinstate the certificate or approve a new one. This 
also applies if we suspend an

[[Page 446]]

exemption, unless we reinstate the exemption.
    Ultimate purchaser means the first person who in good faith 
purchases a new engine or new piece of equipment for purposes other than 
resale.
    United States, in a geographic sense, means the States, the District 
of Columbia, the Commonwealth of Puerto Rico, the Commonwealth of the 
Northern Mariana Islands, Guam, American Samoa, and the U.S. Virgin 
Islands.
    U.S.-directed production volume has the meaning given in the 
standard-setting part.
    Void means to invalidate a certificate or an exemption ab initio 
(``from the beginning''). If we void a certificate, all the engines/
equipment introduced into U.S. commerce under that family for that model 
year are considered uncertified (or nonconforming) and are therefore not 
covered by a certificate of conformity, and you are liable for all 
engines/equipment introduced into U.S. commerce under the certificate 
and may face civil or criminal penalties or both. This applies equally 
to all engines/equipment in the family, including engines/equipment 
introduced into U.S. commerce before we voided the certificate. If we 
void an exemption, all the engines/equipment introduced into U.S. 
commerce under that exemption are considered uncertified (or 
nonconforming), and you are liable for engines/equipment introduced into 
U.S. commerce under the exemption and may face civil or criminal 
penalties or both. You may not sell, offer for sale, or introduce or 
deliver into commerce in the United States or import into the United 
States any additional engines/equipment using the voided exemption.
    Voluntary emission recall means a repair, adjustment, or 
modification program voluntarily initiated and conducted by a 
manufacturer to remedy any emission-related defect for which engine 
owners have been notified.
    We (us, our) means the Administrator of the Environmental Protection 
Agency and any authorized representatives.

[81 FR 74218, Oct. 25, 2016, as amended at 88 FR 4714, Jan. 24, 2023]



Sec.  1068.31  Changing the status of nonroad or 
stationary engines under the definition of ``nonroad engine''.

    This section specifies the provisions that apply when an engine 
previously used in a nonroad application is subsequently used in an 
application other than a nonroad application, or when an engine 
previously used in a stationary application (i.e., an engine that was 
not used as a nonroad engine and that was not used to propel a motor 
vehicle, an aircraft, or equipment used solely for competition) is 
moved.
    (a) Changing the status of a stationary engine to be a new nonroad 
engine as described in paragraph (b) of this section is a violation of 
Sec.  1068.101(a)(1) or (b)(3) unless the engine has been certified to 
be compliant with all requirements of this chapter that apply to new 
nonroad engines of the same type (for example, a compression-ignition 
engine rated at 40 kW) and model year, and is in its certified 
configuration. Note that the definitions of ``model year'' in the 
standard-setting parts generally identify the engine's original date of 
manufacture as the basis for determining which standards apply if it 
becomes a nonroad engine after it is no longer new. For example, see 40 
CFR 1039.801 and 1048.801.
    (b) A stationary engine becomes a new nonroad engine if--
    (1) It is used in an application that meets the criteria specified 
in paragraphs (1)(i) or (ii) in the definition of ``nonroad engine'' in 
Sec.  1068.30.
    (2) It meets the criteria specified in paragraph (1)(iii) of the 
definition of ``nonroad engine'' in Sec.  1068.30 and is moved so that 
it fails to meet (or no longer meets) the criteria specified in 
paragraph (2)(iii) in the definition of ``nonroad engine'' in Sec.  
1068.30.
    (c) A stationary engine does not become a new nonroad engine if it 
is moved but continues to meet the criteria specified in paragraph 
(2)(iii) in the definition of ``nonroad engine'' in Sec.  1068.30 in its 
new location. For example, a transportable engine that is used in a 
single specific location for 18 months and is later moved to a second 
specific location where it will remain for at least 12 months is 
considered to

[[Page 447]]

be a stationary engine in both locations. Note that for stationary 
engines that are neither portable nor transportable in actual use, the 
residence-time restrictions in the definition of ``nonroad engine'' 
generally do not apply.
    (d) Changing the status of a nonroad engine to be a new stationary 
engine as described in paragraph (e) of this section is a violation of 
Sec.  1068.101(a)(1) unless the engine complies with all the 
requirements of this chapter for new stationary engines of the same type 
(for example, a compression-ignition engine rated at 40 kW) and model 
year. For a new stationary engine that is required to be certified under 
40 CFR part 60, the engine must have been certified to be compliant with 
all the requirements that apply to new stationary engines of the same 
type and model year, and must be in its certified configuration. Note 
that the definitions of ``model year'' in the standard-setting parts 
generally identify the engine's original date of manufacture as the 
basis for determining which standards apply if it becomes a stationary 
engine after it is no longer new. For example, see 40 CFR 60.4219 and 
60.4248.
    (e) A nonroad engine ceases to be a nonroad engine and becomes a new 
stationary engine if--
    (1) At any time, it meets the criteria specified in paragraph 
(2)(iii) in the definition of ``nonroad engine'' in Sec.  1068.30. For 
example, a portable generator engine ceases to be a nonroad engine if it 
is used or will be used in a single specific location for 12 months or 
longer. If we determine that an engine will be or has been used in a 
single specific location for 12 months or longer, it ceased to be a 
nonroad engine when it was placed in that location.
    (2) It is otherwise regulated by a federal New Source Performance 
Standard promulgated under section 111 of the Clean Air Act (42 U.S.C. 
7411).
    (f) A nonroad engine ceases to be a nonroad engine if it is used to 
propel a motor vehicle, an aircraft, or equipment used solely for 
competition. See 40 CFR part 86 for requirements applicable to motor 
vehicles and motor vehicle engines. See 40 CFR part 87 for requirements 
applicable to aircraft and aircraft engines. See Sec.  1068.235 for 
requirements applicable to equipment used solely for competition.

[73 FR 59344, Oct. 8, 2008, as amended at 75 FR 23059, Apr. 30, 2010; 81 
FR 74221, Oct. 25, 2016]



Sec.  1068.32  Explanatory terms.

    This section explains how certain phrases and terms are used in 40 
CFR parts 1000 through 1099, especially those used to clarify and 
explain regulatory provisions.
    (a) Types of provisions. The term ``provision'' includes all aspects 
of the regulations in this subchapter U. As described in this section, 
regulatory provisions include standards, requirements, prohibitions, and 
allowances, along with a variety of other types of provisions. In 
certain cases, we may use these terms to apply to some but not all of 
the provisions of a part or section. For example, we may apply the 
allowances of a section for certain engines, but not the requirements. 
We may also apply all provisions except the requirements and 
prohibitions.
    (1) A standard is a requirement established by regulation that 
limits the emissions of air pollutants. Examples of standards include 
numerical emission standards (such as 0.01 g/kW-hr) and design standards 
(such as a closed crankcase standard). Compliance with or conformance to 
a standard is a specific type of requirement, and in some cases a 
standard may be discussed as a requirement. Thus, a statement about the 
requirements of a part or section also applies with respect to the 
standards of the part or section.
    (2) The regulations in subchapter U of this chapter apply other 
requirements in addition to standards. For example, manufacturers are 
required to keep records and provide reports to EPA.
    (3) While requirements state what someone must do, prohibitions 
state what someone may not do. Prohibitions are often referred to as 
prohibited acts or prohibited actions. Most penalties apply for 
violations of prohibitions. A list of prohibitions may therefore include 
the failure to meet a requirement as a prohibited action.
    (4) Allowances provide some form of relief from requirements. This 
may include provisions delaying implementation, establishing exemptions 
or test

[[Page 448]]

waivers, or creating alternative compliance options. Allowances may be 
conditional. For example, we may exempt you from certain requirements on 
the condition that you meet certain other requirements.
    (5) The regulations in subchapter U of this chapter also include 
important provisions that are not standards, requirements, prohibitions, 
or allowances, such as definitions.
    (6) Engines/equipment are generally considered ``subject to'' a 
specific provision if that provision applies, or if it does not apply 
because of an exemption authorized under the regulation. For example, 
locomotives are subject to the provisions of 40 CFR part 1033 even if 
they are exempted from the standards of part 1033.
    (b) Singular and plural. Unless stated otherwise or unless it is 
clear from the regulatory context, provisions written in singular form 
include the plural form and provisions written in plural form include 
the singular form. For example, the statement ``The manufacturer must 
keep this report for three years'' is equivalent to ``The manufacturers 
must keep these reports for three years.''
    (c) Inclusive lists. Lists in the regulations in subchapter U of 
this chapter prefaced by ``including'' or ``this includes'' are not 
exhaustive. The terms ``including'' and ``this includes'' should be read 
to mean ``including but not limited to'' and ``this includes but is not 
limited to''. For example, the phrase ``including small manufacturers'' 
does not exclude large manufacturers. However, prescriptive statements 
to ``include'' specific items (such as those related to recordkeeping 
and reporting requirements) may be exhaustive.
    (d) Notes. Statements that begin with ``Note:'' or ``Note that'' are 
intended to clarify specific regulatory provisions stated elsewhere in 
the regulations in subchapter U of this chapter. By themselves, such 
statements are not intended to specify regulatory requirements. Such 
statements are typically used for regulatory text that, while legally 
sufficient to specify a requirement, may be misunderstood by some 
readers. For example, the regulations might note that a word is defined 
elsewhere in the regulations to have a specific meaning that may be 
either narrower or broader than some readers might assume.
    (e) Examples. Examples provided in the regulations in subchapter U 
of this chapter are typically introduced by either ``for example'' or 
``such as''. Specific examples given in the regulations do not 
necessarily represent the most common examples. The regulations may 
specify examples conditionally (that is, specifying that they are 
applicable only if certain criteria or conditions are met). Lists of 
examples cannot be presumed to be exhaustive lists.
    (f) Generally and typically. Statements that begin with 
``generally'', ``in general'', or ``typically'' should not be read to 
apply universally or absolutely. Rather they are intended to apply for 
the most common circumstances. ``Generally'' and ``typically'' 
statements may be identified as notes as described in paragraph (d) of 
this section.
    (g) Unusual circumstances. The regulations in subchapter U of this 
chapter specify certain allowances that apply ``in unusual 
circumstances''. While it is difficult to precisely define what 
``unusual circumstances'' means, this generally refers to specific 
circumstances that are both rare and unforeseeable. For example, a 
severe hurricane in the northeastern United States may be considered to 
be an unusual circumstance, while a less severe hurricane in the 
southeastern United States may not be. Where the regulations limit an 
allowance to unusual circumstances, manufacturers and others should not 
presume that such an allowance will be available to them. Provisions 
related to unusual circumstances may be described using the phrase 
``normal circumstances'', which are those circumstances that are not 
unusual circumstances.
    (h) Exceptions and other specifications. Regulatory provisions may 
be expressed as a general prohibition, requirement, or allowance that is 
modified by other regulatory text. Such provisions may include phrases 
such as ``unless specified otherwise'', ``except as specified'', or ``as 
specified in this

[[Page 449]]

section''. It is important that the exceptions and the more general 
statement be considered together. This regulatory construct is intended 
to allow the core requirement or allowance to be stated in simple, clear 
sentences, rather than more precise and comprehensive sentences that may 
be misread. For example, where an action is prohibited in most but not 
all circumstances, the provision may state that you may not take the 
action, ``except as specified in this section.'' The exceptions could 
then be stated in subsequent regulatory text.

[81 FR 74221, Oct. 25, 2016]



1068.35  Symbols, acronyms, and abbreviations.

    The following symbols, acronyms, and abbreviations apply to this 
part:

$ U.S. dollars.
CFR Code of Federal Regulations.
disp engine displacement.
EPA Environmental Protection Agency.
kW kilowatt.
L/cyl liters per cylinder.
NARA National Archives and Records Administration.
NOX Oxides of nitrogen.
SAE Society of Automotive Engineers.
SEA selective enforcement audit.
U.S. United States.
U.S.C. United States Code.



Sec.  1068.40  Special provisions for implementing changes
in the regulations in this part.

    (a) During the 12 months following the effective date of any change 
in the provisions of this part, you may ask to apply the previously 
applicable provisions. Note that the effective date is generally 30 or 
60 days after publication in the Federal Register, as noted in the final 
rule. We will generally approve your request if you can demonstrate that 
it would be impractical to comply with the new requirements. We may 
consider the potential for adverse environmental impacts in our 
decision. Similarly, in unusual circumstances, you may ask for relief 
under this paragraph (a) from new requirements that apply under the 
standard-setting part.
    (b) During the 60 days following the effective date of any change in 
the provisions of this part, you may use the previously applicable 
provisions without request if they meet either of the following 
criteria:
    (1) The new provisions require you to redesign your engines/
equipment, modify your engine/equipment labels, or change your 
production procedures.
    (2) The new provisions change what you must include in an 
application for certification that you submit before the end of this 60-
day period. You are not required to amend such applications to comply 
with the new provisions for that model year; however, this allowance 
does not apply for later model years, even if you certify an engine 
family using carryover emission data. This allowance does not affect 
your obligation to provide information that we request separate from an 
application for certification.

[75 FR 23059, Apr. 30, 2010, as amended at 81 FR 74222, Oct. 25, 2016]



Sec.  1068.45  General labeling provisions.

    The provisions of this part and the standard-setting part include a 
variety of labeling requirements. The following general provisions 
apply:
    (a) Permanent labels. Where we specify that you apply a permanent 
label, you must meet the following requirements unless the standard-
setting part includes other specific label requirements:
    (1) Attach the label so no one can remove it without destroying or 
defacing it.
    (2) Make sure it is durable and readable for the engine/equipment's 
entire life.
    (3) Secure it to a part of the engine/equipment needed for normal 
operation and not normally requiring replacement.
    (4) Write it in English.
    (5) Make the labels readily visible to the average person after all 
installation and assembly are complete.
    (b) Removable labels. Where we specify that you apply a removable 
label, it must meet the following conditions:
    (1) You must attach the label in a way that does not allow it to be 
separated from the engine/equipment without a deliberate effort. Note 
that for

[[Page 450]]

exemptions requiring removable labels, the exemption no longer applies 
once the label is separated from the engine/equipment.
    (2) The label must be durable and readable throughout the period of 
its intended purpose. This period generally includes all distribution in 
U.S. commerce during which the exemption applies.
    (3) Except as specified in paragraph (c) of this section, the label 
must be attached directly to the engine/equipment in a visible location. 
We consider a tag that meets the specified requirements to be an 
attached label.
    (c) Labels on packaging. Unless we specify otherwise, where we 
require engine/equipment labels that may be removable, you may instead 
label the packaging if the engines/equipment are packaged together as 
described in this paragraph (c). For example, this may involve packaging 
engines together by attaching them to a rack, binding them together on a 
pallet, or enclosing them in a box. The provisions of this paragraph (c) 
also apply for engines/equipment boxed individually where you do not 
apply labels directly to the engines/equipment. The following provisions 
apply if you label the packaging instead of labeling engines/equipment 
individually:
    (1) You may use the provisions of this paragraph (c) only if all the 
engines/equipment packaged together need the same label.
    (2) You must place the label on the package in a readily visible 
location. This may require labeling the package in multiple locations.
    (3) You must package the engines/equipment such that the labels will 
not be separated from the engines/equipment or otherwise become 
unreadable throughout the period that the label applies. For example, 
labels required for shipping engines to a secondary engine manufacturer 
under Sec.  1068.262 must remain attached and readable until they reach 
the secondary engine manufacturer. Similarly, removable labels specified 
in Sec.  1068.240 for replacement engines must remain attached and 
readable until they reach the point of final installation.
    (4) You are in violation of Sec.  1068.101(a)(1) if such engines/
equipment are removed from the package or are otherwise separated from 
the label before reaching the point at which the label is no longer 
needed.
    (d) Temporary consumer labels. Where we specify that you apply 
temporary consumer labels (including tags), each label must meet the 
following conditions:
    (1) You must attach the label in a way that does not allow it to be 
separated from the engine/equipment without a deliberate effort.
    (2) The label must be sufficiently durable to be readable until it 
reaches the ultimate purchaser.
    (3) The label must be attached directly to the engine/equipment in a 
visible location.
    (e) Prohibitions against removing labels. As specified in Sec.  
1068.101(b)(7), removing permanent labels is prohibited except for 
certain circumstances. Removing temporary or removable labels 
prematurely is also prohibited by Sec.  1068.101(b)(7).
    (f) Identifying emission control systems. If the standard-setting 
part specifies that you use standardized terms and abbreviations to 
identify emission control systems, use terms and abbreviations 
consistent with SAE J1930 (incorporated by reference in Sec.  1068.95).
    (g) Date format. If you use a coded approach to identify the engine/
equipment's date of manufacture, describe or interpret the code in your 
application for certification.
    (h) Branding. The following provisions apply if you identify the 
name and trademark of another company instead of your own on your 
emission control information label, as provided in the standard-setting 
part:
    (1) You must have a contractual agreement with the other company 
that obligates that company to take the following steps:
    (i) Meet the emission warranty requirements that apply under the 
standard-setting part. This may involve a separate agreement involving 
reimbursement of warranty-related expenses.
    (ii) Report all warranty-related information to the certificate 
holder.
    (2) In your application for certification, identify the company 
whose trademark you will use.

[[Page 451]]

    (3) You remain responsible for meeting all the requirements of this 
chapter, including warranty and defect-reporting provisions.

[73 FR 59344, Oct. 8, 2008, as amended at 75 FR 23059, Apr. 30, 2010; 81 
FR 74222, Oct. 25, 2016]



Sec.  1068.50  Adjustable parameters.

    (a) The standard-setting part requires as a condition of 
certification that engines with adjustable parameters meet all the 
requirements of the standard-setting part for any setting in the 
practically adjustable range. This section defines these terms and 
describes general provisions that apply broadly across sectors. This 
section refers to engines, because most adjustable parameters are 
integral to the engine even in the case of equipment-based standards; 
this section also applies for equipment-based adjustable parameters. The 
provisions of this section apply starting with model year 2027 and are 
optional for earlier model years.
    (b) You must use good engineering judgment for all decisions related 
to adjustable parameters. We recommend that you ask for preliminary 
approval for decisions related to new technologies, substantially 
changed engine designs, or new methods for limiting adjustability. The 
standard-setting part describes the information you must include in the 
application for certification related to adjustable parameters. 
Decisions related to adjustable parameters include the following:
    (1) Determining which engine operating parameters qualify as 
adjustable parameters.
    (2) Establishing the adequacy of the limits, stops, seals, 
programming limits, inducements, or other means used to limit 
adjustment, limit reprogramming, or ensure replenishment.
    (3) Defining the practically adjustable range for each such 
parameter.
    (c) For purposes of this section, ``operating parameter'' means any 
feature that can, by the nature of its design, be adjusted to affect 
engine performance. For example, while bolts used to assemble the engine 
are practically adjustable (can be loosened or tightened), they are not 
adjustable parameters because they are not operating parameters. 
Consider all programmable parameters not involving user-selectable 
controls to be a single, collective operating parameter.
    (d) Operating parameters are considered adjustable parameters if 
they are practically adjustable by a user or other person by physical 
adjustment, programmable adjustment, or regular replenishment of a fluid 
or other consumable material. However, an operating parameter is not an 
adjustable parameter if--
    (1) We determine it is permanently sealed or it is not practically 
adjustable using available tools, as described in paragraph (e) of this 
section; or
    (2) We determine that engine operation over the full range of 
adjustment does not affect emissions without also degrading engine 
performance to the extent that operators will be aware of the problem.
    (e) An operating parameter is considered practically adjustable as 
follows:
    (1) Physically adjustable parameters are considered practically 
adjustable if the adjustment is accessible and can be performed by an 
experienced mechanic using appropriate tools within the following time 
and cost thresholds, excluding extraordinary measures:
    (i) For engines at or below 30 kW, physically adjustable parameters 
are considered practically adjustable if a typical user can make 
adjustments with ordinary tools within 15 minutes using service parts 
that cost no more than $30.
    (ii) For 30-560 kW engines, physically adjustable parameters are 
considered practically adjustable if a qualified mechanic can make 
adjustments with ordinary tools within 60 minutes using service parts 
that cost no more than $60.
    (iii) For engines above 560 kW, physically adjustable parameters are 
considered practically adjustable if a qualified mechanic can make 
adjustments with any available supplies and tools within 60 minutes.
    (iv) Cost thresholds in this section are expressed in 2020 dollars. 
Adjust these values for certification by comparing most recently 
available Consumer Price Index for All Urban Consumers (CPI-U) value 
published by the Bureau of Labor Statistics at

[[Page 452]]

www.bls.gov/data/inflation _calculator.htm.
    (v) Cost thresholds do not include the cost of labor or the cost of 
any necessary tools or nonconsumable supplies. Time thresholds refer to 
the time required to access and adjust the parameter, excluding any time 
necessary to purchase parts, tools, or supplies, or to perform testing.
    (vi) The term ``ordinary tools'' has the following meanings for 
different sizes of engines:
    (A) Ordinary tools consist of slotted and Phillips head 
screwdrivers, pliers, hammers, awls, wrenches, electric screwdrivers, 
electric drills, and any tools supplied by the manufacturer, where those 
tools are used for their intended purpose.
    (B) For 30-560 kW engines, ordinary tools includes the tools 
identified in paragraph (e)(1)(vi)(A) of this section and any other hand 
tools, solvents, or other supplies sold at hardware stores, automotive 
parts supply stores or on the internet.
    (vii) The following extraordinary measures are not included when 
determining whether a physically adjustable parameter is considered 
``practically adjustable'' according to the specified time and cost 
thresholds:
    (A) Removing the cylinder head(s) from the engine block.
    (B) Fully or partially removing a carburetor.
    (C) Drilling or grinding through caps or plugs.
    (D) Causing damage to engine or equipment if the associated repair 
would exceed the time or cost thresholds in this paragraph (e)(1).
    (E) Making special tools to override design features that prevent 
adjustment. Note that extraordinary measures do not include purchase of 
such special tools if they become available as described in paragraph 
(e)(1)(vi)(B) of this section.
    (2) A programmable operating parameter is considered ``practically 
adjustable'' if an experienced mechanic can adjust the parameter using 
any available tools (including devices that are used to alter computer 
code). Conversely, such parameters are not practically adjustable if you 
limit access to electronic control modules with password or encryption 
protection. You must have adequate protections in place to prevent 
distribution and use of passwords or encryption keys. This paragraph 
(e)(2) applies for engines with any degree of programmable control. 
Programmable settings are considered practically adjustable if any of 
the following apply:
    (i) The user can make the adjustment by following instructions in 
the owners manual.
    (ii) An experienced mechanic can make the adjustment using ordinary 
digital interface tools for selecting available settings or options as 
described in this paragraph (e)(2).
    (f) The practically adjustable range for physically adjustable 
operating parameters is based on design features to create physical 
limits or stops to limit adjustment. A physical limit or stop is 
adequate for defining the limits of the practically adjustable range if 
it has the following characteristics:
    (1) In the case of a threaded adjustment, the head is sheared off 
after adjustment at the factory or the threads are terminated, pinned, 
or crimped to prevent additional travel without causing damage for which 
the repair would exceed the time or cost thresholds in paragraph (e)(1) 
of this section.
    (2) In the case of fasteners, bimetal springs, or other mechanical 
devices used to limit adjustment, those devices are recessed within a 
larger, permanent body and sealed with a plug, cap, or cover plate that 
limits access to the device consistent with the time and cost thresholds 
in paragraph (e)(1) of this section.
    (3) Operators cannot exceed the travel or rotation limits using 
appropriate tools without causing damage for which the repairs would 
exceed the time or cost thresholds specified in paragraph (e)(1) of this 
section. For example, if a vehicle has a shim, bushing, or other device 
to limit flow rates, range of travel, or other parameters to prevent 
operating outside of a specified range of engine or vehicle speeds, you 
must take steps to prevent operators or mechanics from removing, 
replacing, or altering those parts to operate at a wider range of engine 
or vehicle speeds.

[[Page 453]]

    (g) Apply the following provisions to determine the practically 
adjustable range for programmable parameters that can be adjusted by 
changing software or operating parameters (``reflashed''):
    (1) If an engine includes multiple operating modes or other 
algorithms that can be selected or are easily accessible, consider each 
of the selectable or accessible modes or settings to be within the 
practically adjustable range.
    (2) If you sell or offer to sell software or other tools that an 
experienced mechanic not affiliated with the manufacturer could use to 
reflash or otherwise modify the electronic control module, consider all 
those settings to be within the practically adjustable range.
    (3) The following systems and features illustrate examples of the 
types of programmable settings for which this paragraph (g) applies:
    (i) Air-fuel setpoints for closed-loop fuel systems.
    (ii) Reductant flow systems.
    (iii) Base maps for fuel injection or spark timing.
    (iv) Exhaust gas recirculation maps.
    (h) The following provisions apply for adjustable parameters related 
to elements of design involving consumption and replenishment, such as 
DEF tank fill level and hybrid battery state of charge:
    (1) We will determine the range of adjustability based on the 
likelihood of in-use operation at a given point in the physically 
adjustable range. We may determine that operation in certain subranges 
within the physically adjustable range is sufficiently unlikely that the 
subranges should be excluded from the allowable adjustable range for 
testing. In such cases, the engines/equipment are not required to meet 
the emission standards for operation in an excluded subrange.
    (2) Shipping new engines/equipment in a state or configuration 
requiring replenishment to be within the range of adjustability for a 
certified configuration does not cause a violation of the prohibition in 
Sec.  1068.101(a)(1).
    (i) We will make determinations regarding in-use adjustments of 
adjustable parameters under this section for certifying engines as 
follows:
    (1) Our determinations will depend on in-use maintenance practices 
conforming to the maintenance and service information you provide. For 
example, if your published maintenance instructions describe routine 
procedures for adjusting engines or if you or your dealers make 
specialized tools available to operators, we will conclude that such 
adjustments are likely to occur. Also, your maintenance and service 
information may not specify adjustable ranges that are broader than 
those that you specify in your application for certification.
    (2) We may review manufacturer statements under this section for 
certifying engines for a later model year if we learn from observation 
of in-use engines or other information that a parameter was in fact 
practically adjustable or that the specified operating range was in fact 
not correct. We may require you to include a new adjustable parameter or 
to revise your specified operating range for an adjustable parameter.
    (j) We may inspect your engines at any time to determine whether 
they meet the specifications of this section. We may purchase engines 
for testing, or we may ask you to supply engines for such inspections. 
We will inspect using appropriate tools and time limits and using any 
available devices that alter computer code, as specified in paragraph 
(e)(2) of this section. The inspection will determine the following:
    (1) If the adjustable parameter is limited to the adjustable range 
specified in the manufacturer's certification application.
    (2) If physical stops for physically adjustable parameters can be 
bypassed using methods outlined in paragraph (f) of this section.
    (k) Except as provided in the standard-setting part and this 
paragraph (k), engines are not in the certified configuration if you 
produce them with adjustable parameters set outside the range specified 
in your application for certification. Similarly, engines are not in the 
certified configuration if you produce them with other operating 
parameters that do not conform to the certified configuration. Where we 
determine that you failed to identify something that should be 
considered an

[[Page 454]]

adjustable parameter, we may require you to treat the parameter as 
defective under Sec.  1068.501. If we determine you deliberately 
misrepresented the accessibility of the parameter or that you did not 
act in good faith, we may take action regarding your certificate as 
described in the standard-setting part (see, for example, 40 CFR 
1054.255).
    (l) Nothing in this section limits the tampering prohibition of 
Sec.  1068.101(b)(1) or the defeat device prohibition of Sec.  
1068.101(b)(2).

[87 FR 4714, Jan. 24, 2023]



Sec.  1068.95  Incorporation by reference.

    (a) Certain material is incorporated by reference into this part 
with the approval of the Director of the Federal Register under 5 U.S.C. 
552(a) and 1 CFR part 51. To enforce any edition other than that 
specified in this section, the Environmental Protection Agency must 
publish a document in the Federal Register and the material must be 
available to the public. All approved materials are available for 
inspection at the Air and Radiation Docket and Information Center (Air 
Docket) in the EPA Docket Center (EPA/DC) at Rm. 3334, EPA West Bldg., 
1301 Constitution Ave. NW., Washington, DC The EPA/DC Public Reading 
Room hours of operation are 8:30 a.m. to 4:30 p.m., Monday through 
Friday, excluding legal holidays. The telephone number of the EPA/DC 
Public Reading Room is (202) 566-1744, and the telephone number for the 
Air Docket is (202) 566-1742. These approved materials are also 
available for inspection at the National Archives and Records 
Administration (NARA). For information on the availability of this 
material at NARA, call (202) 741-6030 or go to http://www.archives.gov/
federal _register/code_of_federal _regulations/ibr_ locations.html.. In 
addition, these materials are available from the sources listed below.
    (b) SAE International, 400 Commonwealth Dr., Warrendale, PA 15096-
0001, (724) 776-4841, or http://www.sae.org:
    (1) SAE J1930, Electrical/Electronic Systems Diagnostic Terms, 
Definitions, Abbreviations, and Acronyms, revised October 2008 (``SAE 
J1930''), IBR approved for Sec.  1068.45(f).
    (2) [Reserved]

[81 FR 74222, Oct. 25, 2016]



          Subpart B_Prohibited Actions and Related Requirements



Sec.  1068.101  What general actions does this regulation prohibit?

    This section specifies actions that are prohibited and the maximum 
civil penalties that we can assess for each violation in accordance with 
42 U.S.C. 7522 and 7524. The maximum penalty values listed in paragraphs 
(a) and (b) of this section and in Sec.  1068.125 apply as of August 1, 
2016. As described in paragraph (h) of this section, these maximum 
penalty limits are different for earlier violations and they may be 
adjusted as set forth in 40 CFR part 19.
    (a) The following prohibitions and requirements apply to 
manufacturers of new engines, manufacturers of equipment containing 
these engines, manufacturers of new equipment, and other persons as 
provided by Sec.  1068.1(a), except as described in subparts C and D of 
this part:
    (1) Introduction into commerce. You may not sell, offer for sale, or 
introduce or deliver into commerce in the United States or import into 
the United States any new engine/equipment after emission standards take 
effect for the engine/equipment, unless it is covered by a valid 
certificate of conformity for its model year and has the required label 
or tag. You also may not take any of the actions listed in the previous 
sentence with respect to any equipment containing an engine subject to 
this part's provisions unless the engine is covered by a valid 
certificate of conformity for its model year and has the required engine 
label or tag. We may assess a civil penalty up to $44,539 for each 
engine or piece of equipment in violation.
    (i) For purposes of this paragraph (a)(1), a valid certificate of 
conformity is one that applies for the same model year as the model year 
of the equipment (except as allowed by Sec.  1068.105(a)), covers the 
appropriate category or subcategory of engines/equipment (such as 
locomotive or sterndrive/inboard Marine SI or nonhandheld Small SI), and 
conforms

[[Page 455]]

to all requirements specified for equipment in the standard-setting 
part. Engines/equipment are considered not covered by a certificate 
unless they are in a configuration described in the application for 
certification.
    (ii) The prohibitions of this paragraph (a)(1) also apply for new 
engines you produce to replace an older engine in a piece of equipment, 
except that the engines may qualify for the replacement-engine exemption 
in Sec.  1068.240.
    (iii) The prohibitions of this paragraph (a)(1) also apply for new 
engines that will be installed in equipment subject to equipment-based 
standards, except that the engines may qualify for an exemption under 
Sec.  1068.260(c) or Sec.  1068.262.
    (iv) Where the regulations specify that you are allowed to introduce 
engines/equipment into U.S. commerce without a certificate of 
conformity, you may take any of the otherwise prohibited actions 
specified in this paragraph (a)(1) with respect to those engines/
equipment.
    (2) Reporting and recordkeeping. This chapter requires you to record 
certain types of information to show that you meet our standards. You 
must comply with these requirements to make and maintain required 
records (including those described in Sec.  1068.501). You may not deny 
us access to your records or the ability to copy your records if we have 
the authority to see or copy them. Also, you must give us complete and 
accurate reports and information without delay as required under this 
chapter. Failure to comply with the requirements of this paragraph is 
prohibited. We may assess a civil penalty up to $44,539 for each day you 
are in violation. In addition, knowingly submitting false information is 
a violation of 18 U.S.C. 1001, which may involve criminal penalties and 
up to five years imprisonment.
    (3) Testing and access to facilities. You may not keep us from 
entering your facility to test engines/equipment or inspect if we are 
authorized to do so. Also, you must perform the tests we require (or 
have the tests done for you). Failure to perform this testing is 
prohibited. We may assess a civil penalty up to $44,539 for each day you 
are in violation.
    (b) The following prohibitions apply to everyone with respect to the 
engines and equipment to which this part applies:
    (1) Tampering. You may not remove or render inoperative any device 
or element of design installed on or in engines/equipment in compliance 
with the regulations prior to its sale and delivery to the ultimate 
purchaser. You also may not knowingly remove or render inoperative any 
such device or element of design after such sale and delivery to the 
ultimate purchaser. This includes, for example, operating an engine 
without a supply of appropriate quality urea if the emission control 
system relies on urea to reduce NOX emissions or the use of 
incorrect fuel or engine oil that renders the emission control system 
inoperative. Section 1068.120 describes how this applies to rebuilding 
engines. See the standard-setting part, which may include additional 
provisions regarding actions prohibited by this requirement. For a 
manufacturer or dealer, we may assess a civil penalty up to $44,539 for 
each engine or piece of equipment in violation. For anyone else, we may 
assess a civil penalty up to $4,454 for each engine or piece of 
equipment in violation. This prohibition does not apply in any of the 
following situations:
    (i) You need to repair the engine/equipment and you restore it to 
proper functioning when the repair is complete.
    (ii) You need to modify the engine/equipment to respond to a 
temporary emergency and you restore it to proper functioning as soon as 
possible.
    (iii) You modify new engines/equipment that another manufacturer has 
already certified to meet emission standards and recertify them under 
your own family. In this case you must tell the original manufacturer 
not to include the modified engines/equipment in the original family.
    (2) Defeat devices. You may not knowingly manufacture, sell, offer 
to sell, or install, any component that bypasses, impairs, defeats, or 
disables the control of emissions of any regulated pollutant, except as 
explicitly allowed by the standard-setting part. We may assess a

[[Page 456]]

civil penalty up to $4,454 for each component in violation.
    (3) Stationary engines. For an engine that is excluded from any 
requirements of this chapter because it is a stationary engine, you may 
not move it or install it in any mobile equipment except as allowed by 
the provisions of this chapter. You may not circumvent or attempt to 
circumvent the residence-time requirements of paragraph (2)(iii) of the 
nonroad engine definition in Sec.  1068.30. Anyone violating this 
paragraph (b)(3) is deemed to be a manufacturer in violation of 
paragraph (a)(1) of this section. We may assess a civil penalty up to 
$44,539 for each engine or piece of equipment in violation.
    (4) Competition engines/equipment. (i) For uncertified engines/
equipment that are excluded or exempted as new engines/equipment from 
any requirements of this chapter because they are to be used solely for 
competition, you may not use any of them in a manner that is 
inconsistent with use solely for competition. Anyone violating this 
paragraph (b)(4)(i) is deemed to be a manufacturer in violation of 
paragraph (a)(1) of this section. We may assess a civil penalty up to 
$44,539 for each engine or piece of equipment in violation. (ii) For 
certified nonroad engines/equipment that qualify for exemption from the 
tampering prohibition as described in Sec.  1068.235 because they are to 
be used solely for competition, you may not use any of them in a manner 
that is inconsistent with use solely for competition. Anyone violating 
this paragraph (b)(4)(ii) is in violation of paragraph (b)(1) or (2) of 
this section.
    (5) Importation. You may not import an uncertified engine or piece 
of equipment if it is defined to be new in the standard-setting part 
with a model year for which emission standards applied. Anyone violating 
this paragraph (b)(5) is deemed to be a manufacturer in violation of 
paragraph (a)(1) of this section. We may assess a civil penalty up to 
$44,539 for each engine or piece of equipment in violation. Note the 
following:is excluded
    (i) The definition of new is broad for imported engines/equipment; 
uncertified engines and equipment (including used engines and equipment) 
are generally considered to be new when imported.
    (ii) Used engines/equipment that were originally manufactured before 
applicable EPA standards were in effect are generally not subject to 
emission standards.
    (6) Warranty, recall, and maintenance instructions. You must meet 
your obligation to honor your emission-related warranty under Sec.  
1068.115, including any commitments you identify in your application for 
certification. You must also fulfill all applicable requirements under 
subpart F of this part related to emission-related defects and recalls. 
You must also provide emission-related installation and maintenance 
instructions as described in the standard-setting part. Failure to meet 
these obligations is prohibited. Also, except as specifically provided 
by regulation, you are prohibited from directly or indirectly 
communicating to the ultimate purchaser or a later purchaser that the 
emission-related warranty is valid only if the owner has service 
performed at authorized facilities or only if the owner uses authorized 
parts, components, or systems. We may assess a civil penalty up to 
$44,539 for each engine or piece of equipment in violation.
    (7) Labeling. (i) You may not remove or alter an emission control 
information label or other required permanent label except as specified 
in this paragraph (b)(7) or otherwise allowed by this chapter. Removing 
or altering an emission control information label is a violation of 
paragraph (b)(1) of this section. However, it is not a violation to 
remove a label in the following circumstances:
    (A) The engine is destroyed, is permanently disassembled, or 
otherwise loses its identity such that the original title to the engine 
is no longer valid.
    (B) The regulations specifically direct you to remove the label. For 
example, see Sec.  1068.235.
    (C) The part on which the label is mounted needs to be replaced. In 
this case, you must have a replacement part with a duplicate of the 
original label installed by the certifying manufacturer or an authorized 
agent, except that the replacement label may omit the date of 
manufacture if applicable.

[[Page 457]]

We generally require labels to be permanently attached to parts that 
will not normally be replaced, but this provision allows for 
replacements in unusual circumstances, such as damage in a collision or 
other accident.
    (D) The original label is incorrect, provided that it is replaced 
with the correct label from the certifying manufacturer or an authorized 
agent. This allowance to replace incorrect labels does not affect 
whether the application of an incorrect original label is a violation.
    (ii) Removing or altering a temporary or removable label contrary to 
the provisions of this paragraph (b)(7)(ii) is a violation of paragraph 
(b)(1) of this section.
    (A) For labels identifying temporary exemptions, you may not remove 
or alter the label while the engine/equipment is in an exempt status. 
The exemption is automatically revoked for each engine/equipment for 
which the label has been removed.
    (B) For temporary or removable consumer information labels, only the 
ultimate purchaser may remove the label.
    (iii) You may not apply a false emission control information label. 
You also may not manufacture, sell, or offer to sell false labels. The 
application, manufacture, sale, or offer for sale of false labels is a 
violation of this section (such as paragraph (a)(1) or (b)(2) of this 
section). Note that applying an otherwise valid emission control 
information label to the wrong engine is considered to be applying a 
false label.
    (c) If you cause someone to commit a prohibited act in paragraph (a) 
or (b) of this section, you are in violation of that prohibition.
    (d) Exemptions from these prohibitions are described in subparts C 
and D of this part and in the standard-setting part.
    (e) The standard-setting parts describe more requirements and 
prohibitions that apply to manufacturers (including importers) and 
others under this chapter.
    (f) The specification of prohibitions and penalties in this part 
does not limit the prohibitions and penalties described in the Clean Air 
Act. Additionally, a single act may trigger multiple violations under 
this section and the Act. We may pursue all available administrative, 
civil, or criminal remedies for those violations even if the regulation 
references only a single prohibited act in this section.
    (g) [Reserved]
    (h) The maximum penalty values listed in paragraphs (a) and (b) of 
this section and in Sec.  1068.125 apply as of August 1, 2016. Maximum 
penalty values for earlier violations are published in 40 CFR part 19. 
Maximum penalty limits may be adjusted after August 1, 2016 based on the 
Consumer Price Index. The specific regulatory provisions for changing 
the maximum penalties, published in 40 CFR part 19, reference the 
applicable U.S. Code citation on which the prohibited action is based. 
The following table is shown here for informational purposes:

Table 1 of Sec.   1068.101--Legal Citation for Specific Prohibitions for
                   Determining Maximum Penalty Amounts
------------------------------------------------------------------------
    Part 1068 regulatory                             U.S. Code citation
   citation of prohibited      General description    for Clean Air Act
           action                of prohibition           authority
------------------------------------------------------------------------
Sec.   1068.101(a)(1).......  Introduction into     42 U.S.C. 7522(a)(1)
                               U.S. commerce of an   and (a)(4).
                               uncertified source.
Sec.   1068.101(a)(2).......  Failure to provide    42 U.S.C.
                               information.          7522(a)(2).
Sec.   1068.101(a)(3).......  Denying access to     42 U.S.C.
                               facilities.           7522(a)(2).
Sec.   1068.101(b)(1).......  Tampering with        42 U.S.C.
                               emission controls     7522(a)(3).
                               by a manufacturer
                               or dealer.
                              Tampering with
                               emission controls
                               by someone other
                               than a manufacturer
                               or dealer.
Sec.   1068.101(b)(2).......  Sale or use of a      42 U.S.C.
                               defeat device.        7522(a)(3).
Sec.   1068.101(b)(3).......  Mobile use of a       42 U.S.C. 7522(a)(1)
                               stationary engine.    and (a)(4).
Sec.   1068.101(b)(4).......  Noncompetitive use    42 U.S.C. 7522(a)(1)
                               of uncertified        and (a)(4).
                               engines/equipment
                               that is exempted
                               for competition.
Sec.   1068.101(b)(5).......  Importation of an     42 U.S.C. 7522(a)(1)
                               uncertified source.   and (a)(4).
Sec.   1068.101(b)(6).......  Recall and warranty.  42 U.S.C.
                                                     7522(a)(4).
Sec.   1068.101(b)(7).......  Removing labels.....  42 U.S.C.
                                                     7522(a)(3).
------------------------------------------------------------------------


[[Page 458]]


[75 FR 23059, Apr. 30, 2010; 81 FR 74222, Oct. 25, 2016; 88 FR 4716, 
Jan. 24, 2023]



Sec.  1068.103  Provisions related to the duration and applicability
of certificates of conformity.

    (a) Engines/equipment covered by a certificate of conformity are 
limited to those that are produced during the period specified in the 
certificate and conform to the specifications described in the 
certificate and the associated application for certification. For the 
purposes of this paragraph (a), ``specifications'' includes the emission 
control information label and any conditions or limitations identified 
by the manufacturer or EPA. For example, if the application for 
certification specifies certain engine configurations, the certificate 
does not cover any configurations that are not specified. We may ignore 
any information provided in the application that we determine is not 
relevant to a demonstration of compliance with applicable regulations, 
such as your projected production volumes in many cases.
    (b) Unless the standard-setting part specifies otherwise, determine 
the production period corresponding to each certificate of conformity as 
specified in this paragraph (b). In general, the production period is 
the manufacturer's annual production period identified as a model year.
    (1) For engines/equipment subject to emission standards based on 
model years, the first day of the annual production period can be no 
earlier than January 2 of the calendar year preceding the year for which 
the model year is named, or the earliest date of manufacture for any 
engine/equipment in the engine family, whichever is later. The last day 
of the annual production period can be no later than December 31 of the 
calendar year for which the model year is named or the latest date of 
manufacture for any engine/equipment in the engine family, whichever is 
sooner. Note that this approach limits how you can designate a model 
year for your engines/equipment; however, it does not limit your ability 
to meet more stringent emission standards early where this is permitted 
in the regulation.
    (2) For fuel-system components certified to evaporative emission 
standards based on production periods rather than model years, the 
production period is either the calendar year or a longer period we 
specify consistent with the manufacturer's normal production practices.
    (c) A certificate of conformity will not cover engines/equipment you 
produce with a date of manufacture earlier than the date you submit the 
application for certification for the family. You may start to produce 
engines/equipment after you submit an application for certification and 
before the effective date of a certificate of conformity, subject to the 
following conditions:
    (1) The engines/equipment must conform in all material respects to 
the engines/equipment described in your application. Note that if we 
require you to modify your application, you must ensure that all 
engines/equipment conform to the specifications of the modified 
application.
    (2) The engines/equipment may not be sold, offered for sale, 
introduced into U.S. commerce, or delivered for introduction into U.S. 
commerce before the effective date of the certificate of conformity.
    (3) You must notify us in your application for certification that 
you plan to use the provisions of this paragraph (c) and when you intend 
to start production. If the standard-setting part specifies mandatory 
testing for production-line engines, you must start testing as directed 
in the standard-setting part based on your actual start of production, 
even if that occurs before we approve your certification. You must also 
agree to give us full opportunity to inspect and/or test the engines/
equipment during and after production. For example, we must have the 
opportunity to specify selective enforcement audits as allowed by the 
standard-setting part and the Clean Air Act as if the engines/equipment 
were produced after the effective date of the certificate.
    (4) See Sec.  1068.262 for special provisions that apply for 
secondary engine manufacturers receiving shipment of partially complete 
engines before the effective date of a certificate.

[[Page 459]]

    (d) The prohibition in Sec.  1068.101(a)(1) against offering to sell 
engines/equipment without a valid certificate of conformity generally 
does not apply for engines/equipment that have not yet been produced. 
You may contractually agree to produce engines/equipment before 
obtaining the required certificate of conformity. This is intended to 
allow manufacturers of low-volume products to establish a sufficient 
market for engines/equipment before going through the effort to certify.
    (e) Engines/equipment with a date of manufacture after December 31 
of the calendar year for which a model year is named are not covered by 
the certificate of conformity for that model year. You must submit an 
application for a new certificate of conformity demonstrating compliance 
with applicable standards even if the engines/equipment are identical to 
those with a date of manufacture before December 31.
    (f) The flexible approach to naming the annual production period 
described in paragraph (b)(1) of this section is intended to allow you 
to introduce new products at any point during the year. This is based on 
the expectation that production periods generally run on consistent 
schedules from year to year. You may not use this flexibility to arrange 
your production periods such that you can avoid annual certification.
    (g) An engine is generally assigned a model year based on its date 
of manufacture, which is typically based on the date the crankshaft is 
installed in the engine (see Sec.  1068.30). You may not circumvent the 
provisions of Sec.  1068.101(a)(1) by stockpiling engines with a date of 
manufacture before new or changed emission standards take effect by 
deviating from your normal production and inventory practices. (For 
purposes of this paragraph (g), normal production and inventory 
practices means those practices you typically use for similar families 
in years in which emission standards do not change. We may require you 
to provide us routine production and inventory records that document 
your normal practices for the preceding eight years.) For most engines 
you should plan to complete the assembly of an engine of a given model 
year into its certified configuration within the first week after the 
end of the model year if new emission standards start to apply in that 
model year. For special circumstances it may be appropriate for your 
normal business practice to involve more time. For engines with per-
cylinder displacement below 2.5 liters, if new emission standards start 
to apply in a given year, we would consider an engine not to be covered 
by a certificate of conformity for the preceding model year if the 
engine is not assembled in a compliant configuration within 30 days 
after the end of the model year for that engine family. (Note: an engine 
is considered ``in a compliant configuration'' without being fully 
assembled if Sec.  1068.260(a) or (b) authorizes shipment of the engine 
without certain components.) For example, in the case where new 
standards apply in the 2010 model year, and your normal production 
period is based on the calendar year, you must complete the assembly of 
all your 2009 model year engines before January 31, 2010, or an earlier 
date consistent with your normal production and inventory practices. For 
engines with per-cylinder displacement at or above 2.5 liters, this time 
may not exceed 60 days. Note that for the purposes of this paragraph 
(g), an engine shipped under Sec.  1068.261 is deemed to be a complete 
engine. Note also that Sec.  1068.245 allows flexibility for additional 
time in unusual circumstances. Note finally that disassembly of complete 
engines and reassembly (such as for shipment) does not affect the 
determination of model year; the provisions of this paragraph (g) apply 
based on the date on which initial assembly is complete.
    (h) This paragraph (h) describes the effect of suspending, revoking, 
or voiding a certificate of conformity. See the definitions of 
``suspend,'' ``revoke,'' and ``void'' in Sec.  1068.30. Engines/
equipment produced at a time when the otherwise applicable certificate 
of conformity has been suspended or revoked are not covered by a 
certificate of conformity. Where a certificate of conformity is void, 
all engines/equipment produced under that certificate of conformity

[[Page 460]]

are not and were not covered by a certificate of conformity. In cases of 
suspension, engines/equipment will be covered by a certificate only if 
they are produced after the certificate is reinstated or a new 
certificate is issued. In cases of revocation and voiding, engines/
equipment will be covered by a certificate only if they are produced 
after we issue a new certificate. 42 U.S.C. 7522(a)(1) and Sec.  
1068.101(a)(1) prohibit selling, offering for sale, introducing into 
commerce, delivering for introduction into commerce, and importing 
engines/equipment that are not covered by a certificate of conformity, 
and they prohibit anyone from causing another to violate these 
prohibitions.
    (i) You may transfer a certificate to another entity only in the 
following cases:
    (1) You may transfer a certificate to a parent company, including a 
parent company that purchases your company after we have issued your 
certificate.
    (2) You may transfer a certificate to a subsidiary including a 
subsidiary you purchase after we have issued your certificate.
    (3) You may transfer a certificate to a subsidiary of your parent 
company.

[81 FR 74224, Oct. 25, 2016]



Sec.  1068.105  What other provisions apply to me specifically
if I manufacture equipment needing certified engines?

    This section describes general provisions that apply to equipment 
manufacturers for sources subject to engine-based standards. See the 
standard-setting part for any requirements that apply for certain 
applications. See Sec.  1068.101 for penalties associated with 
violations under this section and for other prohibitions related to your 
equipment.
    (a) Transitioning to new engine-based standards. If new engine-based 
emission standards apply in a given model year, your equipment produced 
in that calendar year (or later) must have engines that are certified to 
the new standards, except that you may continue to use up normal 
inventories of engines that were built before the date of the new or 
changed standards. For purposes of this paragraph (a), normal inventory 
applies for engines you possess and engines from your engine supplier's 
normal inventory. (Note: this paragraph (a) does not apply in the case 
of new remanufacturing standards.) We may require you and your engine 
suppliers to provide us routine production and/or inventory records that 
document your normal practices for the preceding eight years. For 
example, if you have records documenting that your normal inventory 
practice is to keep on hand a one-month supply of engines based on your 
upcoming production schedules, and a new tier of standards starts to 
apply for the 2015 model year, you may order engines consistent with 
your normal inventory requirements late in the engine manufacturer's 
2014 model year and install those engines in your equipment consistent 
with your normal production schedule. Also, if your model year starts 
before the end of the calendar year preceding new standards, you may use 
engines from the previous model year for those units you completely 
assemble before January 1 of the year that new standards apply. If 
emission standards for the engine do not change in a given model year, 
you may continue to install engines from the previous model year without 
restriction (or any earlier model year for which the same standards 
apply). You may not circumvent the provisions of Sec.  1068.101(a)(1) by 
stockpiling engines that were built before new or changed standards take 
effect. Similarly, you may not circumvent the provisions of Sec.  
1068.101(a)(1) by knowingly installing engines that were stockpiled by 
engine suppliers in violation of Sec.  1068.103(f). Note that this 
allowance does not apply for equipment subject to equipment-based 
standards. See 40 CFR 1060.601 for similar provisions that apply for 
equipment subject to evaporative emission standards. Note that the 
standard-setting part may impose further restrictions on using up 
inventories of engines from an earlier model year under this paragraph 
(a).
    (b) Installing engines or certified components. The provisions in 
Sec.  1068.101(a)(1) generally prohibit you from introducing into U.S. 
commerce any new equipment that includes engines not covered by a 
certificate of

[[Page 461]]

conformity. In addition, you must follow the engine manufacturer's 
emission-related installation instructions. For example, you may need to 
constrain where you place an exhaust aftertreatment device or integrate 
into your equipment models a device for sending visual or audible 
signals to the operator. Similarly, you must follow the emission-related 
installation instructions from the manufacturer of a component that has 
been certified for controlling evaporative emissions under 40 CFR part 
1060. Not meeting the manufacturer's emission-related installation 
instructions is a violation of one or more of the prohibitions of Sec.  
1068.101. See Sec.  1068.261 for special provisions that apply when the 
engine manufacturer delegates final assembly of emission controls to 
you.
    (c) Attaching a duplicate label. If you obscure the engine's label, 
you must do four things to avoid violating Sec.  1068.101(a)(1):
    (1) Send a request for duplicate labels in writing on your company's 
letterhead to the engine manufacturer. Include the following information 
in your request:
    (i) Identify the type of equipment and the specific engine and 
equipment models needing duplicate labels.
    (ii) Identify the family (from the original engine label).
    (iii) State the reason that you need a duplicate label for each 
equipment model.
    (iv) Identify the number of duplicate labels you will need.
    (2) Permanently attach the duplicate label to your equipment by 
securing it to a part needed for normal operation and not normally 
requiring replacement. Make sure an average person can easily read it. 
Note that attaching an inaccurate duplicate label may be a violation of 
Sec.  1068.101(b)(7).
    (3) Destroy any unused duplicate labels if you find that you will 
not need them.
    (4) Keep the following records for at least eight years after the 
end of the model year identified on the engine label:
    (i) Keep a copy of your written request.
    (ii) Keep drawings or descriptions that show how you apply the 
duplicate labels to your equipment.
    (iii) Maintain a count of those duplicate labels you use and those 
you destroy.

[73 FR 59344, Oct. 8, 2008, as amended at 75 FR 23062, Apr. 30, 2010; 81 
FR 74225, Oct. 25, 2016]



Sec.  1068.110  Other provisions for engines/equipment in service.

    (a) Aftermarket parts and service. As the certifying manufacturer, 
you may not require anyone to use your parts or service to maintain or 
repair an engine or piece of equipment, unless we approve this in your 
application for certification. It is a violation of the Clean Air Act 
for anyone to manufacture any part if one of its main effects is to 
reduce the effectiveness of the emission controls. See Sec.  
1068.101(b)(2).
    (b) Certifying aftermarket parts. As the manufacturer or rebuilder 
of an aftermarket engine or equipment part, you may--but are not 
required to--certify according to 40 CFR part 85, subpart V, that using 
the part will not cause engines/equipment to fail to meet emission 
standards. Whether you certify or not, you must keep any information 
showing how your parts or service affect emissions.
    (c) Compliance with standards. We may test engines and equipment to 
investigate compliance with emission standards and other requirements. 
We may also require the manufacturer to do this testing.
    (d) Defeat devices. We may test components, engines, and equipment 
to investigate potential defeat devices. We may also require the 
manufacturer to do this testing. If we choose to investigate one of your 
designs, we may require you to show us that a component is not a defeat 
device, and that an engine/equipment does not have a defeat device. To 
do this, you may have to share with us information regarding test 
programs, engineering evaluations, design specifications, calibrations, 
on-board computer algorithms, and design strategies. It is a violation 
of the Clean Air Act for anyone to make, install or use defeat devices 
as described in Sec.  1068.101(b)(2) and the standard-setting part.

[[Page 462]]

    (e) Warranty and maintenance. Owners are responsible for properly 
maintaining their engines/equipment; however, owners may make warranty 
claims against the manufacturer for all expenses related to diagnosing 
and repairing or replacing emission-related parts, as described in Sec.  
1068.115. Manufacturers may ask to limit diagnosis and repair to 
authorized service facilities, provided this does not limit their 
ability to meet their warranty obligations under Sec.  1068.115. The 
warranty period begins when the equipment is first placed into service. 
See the standard-setting part for specific requirements. It is a 
violation of the Clean Air Act for anyone to disable emission controls; 
see Sec.  1068.101(b)(1) and the standard-setting part.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74225, Oct. 25, 2016]



Sec.  1068.115  What are manufacturers' emission-related
warranty requirements?

    Section 207(a) of the Clean Air Act (42 U.S.C. 7541(a)) requires 
certifying manufacturers to warrant to purchasers that their engines/
equipment are designed, built, and equipped to conform at the time of 
sale to the applicable regulations for their full useful life, including 
a warranty that the engines/equipment are free from defects in materials 
and workmanship that would cause any engine/equipment to fail to conform 
to the applicable regulations during the specified warranty period. This 
section codifies the warranty requirements of section 207(a) without 
intending to limit these requirements.
    (a) As a certifying manufacturer, you may deny warranty claims only 
for failures that have been caused by the owner's or operator's improper 
maintenance or use, by accidents for which you have no responsibility, 
or by acts of God. For example, you would not need to honor warranty 
claims for failures that have been directly caused by the operator's 
abuse of the engine/equipment or the operator's use of the engine/
equipment in a manner for which it was not designed and are not 
attributable to you in any way.
    (b) As a certifying manufacturer, you may not deny emission-related 
warranty claims based on any of the following:
    (1) Maintenance or other service you or your authorized facilities 
performed.
    (2) Engine/equipment repair work that an operator performed to 
correct an unsafe, emergency condition attributable to you as long as 
the operator tries to restore the engine/equipment to its proper 
configuration as soon as possible.
    (3) Any action or inaction by the operator unrelated to the warranty 
claim.
    (4) Maintenance that was performed more frequently than you specify.
    (5) Anything that is your fault or responsibility.
    (6) The use of any fuel that is commonly available where the 
equipment operates unless your written maintenance instructions state 
that this fuel would harm the equipment's emission control system and 
operators can readily find the proper fuel.



Sec.  1068.120  Requirements for rebuilding engines.

    (a) This section describes the steps to take when rebuilding engines 
to avoid violating the tampering prohibition in Sec.  1068.101(b)(1). 
These requirements apply to anyone rebuilding an engine subject to this 
part, but the recordkeeping requirements in paragraphs (j) and (k) of 
this section apply only to businesses. For maintenance or service that 
is not rebuilding, including any maintenance related to evaporative 
emission controls, you may not make changes that might increase 
emissions of any regulated pollutant, but you do not need to keep any 
records.
    (b) The term ``rebuilding'' refers to a rebuild of an engine or 
engine system, including a major overhaul in which you replace the 
engine's pistons or power assemblies or make other changes that 
significantly increase the service life of the engine. It also includes 
replacing or rebuilding an engine's turbocharger or aftercooler or the 
engine's systems for fuel metering or electronic control so that it 
significantly increases the service life of the engine. For these 
provisions, rebuilding may or may not involve removing the engine from 
the equipment. Rebuilding

[[Page 463]]

does not normally include the following:
    (1) Scheduled emission-related maintenance that the standard-setting 
part allows during the useful life period (such as replacing fuel 
injectors).
    (2) Unscheduled maintenance that occurs commonly within the useful 
life period. For example, replacing a water pump is not rebuilding an 
engine.
    (c) [Reserved]
    (d) If you rebuild an engine or engine system, you must have a 
reasonable technical basis for knowing that the rebuilt engine's 
emission control system performs as well as, or better than, it performs 
in its certified configuration. Identify the model year of the resulting 
engine configuration. You have a reasonable basis if you meet two main 
conditions:
    (1) Install parts--new, used, or rebuilt--so a person familiar with 
engine design and function would reasonably believe that the engine with 
those parts will control emissions of all pollutants at least to the 
same degree as with the original parts. For example, it would be 
reasonable to believe that parts performing the same function as the 
original parts (and to the same degree) would control emissions to the 
same degree as the original parts.
    (2) Adjust parameters or change design elements only according to 
the original engine manufacturer's instructions. Or, if you differ from 
these instructions, you must have data or some other technical basis to 
show you should not expect in-use emissions to increase.
    (e) If the rebuilt engine remains installed or is reinstalled in the 
same piece of equipment, you must rebuild it to the original 
configuration, except as allowed by this paragraph (e). You may rebuild 
it to a different certified configuration of the same or later model 
year. You may also rebuild it to a certified configuration from an 
earlier model year as long as the earlier configuration is as clean or 
cleaner than the original configuration. For purposes of this paragraph 
(e), ``as clean or cleaner'' means one of the following:
    (1) For engines not certified with a Family Emission Limit for 
calculating credits for a particular pollutant, this means that the same 
emission standard applied for both model years. This includes 
supplemental standards such as Not-to-Exceed standards.
    (2) For engines certified with a Family Emission Limit for a 
particular pollutant, this means that the configuration to which the 
engine is being rebuilt has a Family Emission Limit for that pollutant 
that is at or below the standard that applied to the engine originally, 
and is at or below the original Family Emission Limit.
    (f) A rebuilt engine or other used engine may replace a certified 
engine in a piece of equipment only if the engine was built and/or 
rebuilt to a certified configuration meeting equivalent or more 
stringent emission standards. Note that a certified configuration would 
generally include more than one model year. A rebuilt engine being 
installed that is from the same model year or a newer model year than 
the engine being replaced meets this requirement. The following examples 
illustrate the provisions of this paragraph (f):
    (1) In most cases, you may use a rebuilt Tier 2 engine to replace a 
Tier 1 engine or another Tier 2 engine.
    (2) You may use a rebuilt Tier 1 engine to replace a Tier 2 engine 
if the two engines differ only with respect to model year or other 
characteristics unrelated to emissions since such engines would be 
considered to be in the same configuration. This may occur if the Tier 1 
engine had emission levels below the Tier 2 standards or if the Tier 2 
engine was certified with a Family Emission Limit for calculating 
emission credits.
    (3) You may use a rebuilt engine that originally met the Tier 1 
standards without certification, as provided under Sec.  1068.265, to 
replace a certified Tier 1 engine. This may occur for engines produced 
under a Transition Program for Equipment Manufacturers such as that 
described in 40 CFR 1039.625.
    (4) You may never replace a certified engine with an engine rebuilt 
to a configuration that does not meet EPA

[[Page 464]]

emission standards. Note that, for purposes of this paragraph (f)(4), a 
configuration is considered to meet EPA emission standards if it was 
previously certified or was otherwise shown to meet emission standards 
(see Sec.  1068.265).
    (5) The standard-setting part may apply further restrictions to 
situations involving installation of used engines to repower equipment. 
For example, see 40 CFR part 1037 for provisions that apply for glider 
vehicles.
    (g) Do not erase or reset emission-related codes or signals from 
onboard monitoring systems without diagnosing and responding 
appropriately to any diagnostic codes. This requirement applies 
regardless of the manufacturer's reason for installing the monitoring 
system and regardless of its form or interface. Clear any codes from 
diagnostic systems when you return the rebuilt engine to service. Do not 
disable a diagnostic signal without addressing its cause.
    (h) When you rebuild an engine, check, clean, adjust, repair, or 
replace all emission-related components (listed in Appendix I of this 
part) as needed according to the original manufacturer's recommended 
practice. In particular, replace oxygen sensors, replace the catalyst if 
there is evidence of malfunction, clean gaseous fuel-system components, 
and replace fuel injectors (if applicable), unless you have a reasonable 
technical basis for believing any of these components do not need 
replacement.
    (i) If you are installing an engine that someone else has rebuilt, 
check all emission-related components listed in Appendix I of this part 
as needed according to the original manufacturer's recommended practice.
    (j) Keep at least the following records for all engines except 
spark-ignition engines with total displacement below 225 cc:
    (1) Identify the hours of operation (or mileage, as appropriate) at 
the time of rebuild. These may be noted as approximate values if the 
engine has no hour meter (or odometer).
    (2) Identify the work done on the engine or any emission-related 
control components, including a listing of parts and components you 
used.
    (3) Describe any engine parameter adjustments.
    (4) Identify any emission-related codes or signals you responded to 
and reset.
    (k) You must show us or send us your records if we ask for them. 
Keep records for at least two years after rebuilding an engine. Keep 
them in any format that allows us to readily review them.
    (1) You do not need to keep information that is not reasonably 
available through normal business practices. We do not expect you to 
have information that you cannot reasonably access.
    (2) You do not need to keep records of what other companies do.
    (3) You may keep records based on families rather than individual 
engines if that is the way you normally do business.

[73 FR 59344, Oct. 8, 2008, as amended at 75 FR 23062, Apr. 30, 2010; 81 
FR 74225, Oct. 25, 2016]



Sec.  1068.125  What happens if I violate the regulations?

    (a) Civil penalties and injunctions. We may bring a civil action to 
assess and recover civil penalties and/or enjoin and restrain violations 
in the United States District Court for the district where you allegedly 
violated a requirement, or the district where you live or have your main 
place of business. Actions to assess civil penalties or restrain 
violations of Sec.  1068.101 must be brought by and in the name of the 
United States. The selected court has jurisdiction to restrain 
violations and assess civil penalties.
    (1) To determine the amount of a civil penalty and reach a just 
conclusion, the court considers these factors:
    (i) The seriousness of your violation.
    (ii) How much you benefited or saved because of the violation.
    (iii) The size of your business.
    (iv) Your history of compliance with Title II of the Clean Air Act 
(42 U.S.C. 7401-7590).
    (v) What you did to remedy the violation.
    (vi) How the penalty will affect your ability to continue in 
business.
    (vii) Such other matters as justice may require.

[[Page 465]]

    (2) Subpoenas for witnesses who must attend a district court in any 
district may apply to any other district.
    (b) Administrative penalties. Instead of bringing a civil action, we 
may assess administrative penalties if the total is less than $356,312 
against you individually. This maximum penalty may be greater if the 
Administrator and the Attorney General jointly determine that a greater 
administrative penalty assessment is appropriate, or if the limit is 
adjusted under 40 CFR part 19. No court may review this determination. 
Before we assess an administrative penalty, you may ask for a hearing as 
described in subpart G of this part. The Administrator may compromise or 
remit, with or without conditions, any administrative penalty that may 
be imposed under this section.
    (1) To determine the amount of an administrative penalty, we will 
consider the factors described in paragraph (a)(1) of this section.
    (2) An administrative order we issue under this paragraph (b) 
becomes final 30 days after we issue it unless you ask for judicial 
review by that time (see paragraph (c) of this section). You may ask for 
review by any of the district courts listed in paragraph (a) of this 
section. Send the Administrator a copy of the filing by certified mail.
    (3) We will not pursue an administrative penalty for a particular 
violation if either of the following two conditions is true:
    (i) We are separately prosecuting the violation under this subpart.
    (ii) We have issued a final order for a violation, no longer subject 
to judicial review, for which you have already paid a penalty.
    (c) Judicial review. If you ask a court to review a civil or 
administrative penalty, we will file in the appropriate court within 30 
days of your request a certified copy or certified index of the record 
on which the court or the Administrator issued the order.
    (1) The judge may set aside or remand any order issued under this 
section only if one of the following is true:
    (i) Substantial evidence does not exist in the record, taken as a 
whole, to support finding a violation.
    (ii) The Administrator's assessment of the penalty is an abuse of 
discretion.
    (2) The judge may not add civil penalties unless our penalty is an 
abuse of discretion that favors you.
    (d) Effect of enforcement actions on other requirements. Our pursuit 
of civil or administrative penalties does not affect or limit our 
authority to enforce any provisions of this chapter.
    (e) Penalties. In any proceedings, the United States government may 
seek to collect civil penalties assessed under this section.
    (1) Once a penalty assessment is final, if you do not pay it, the 
Administrator will ask the Attorney General to bring a civil action in 
an appropriate district court to recover the money. We may collect 
interest from the date of the final order or final judgment at rates 
established by the Internal Revenue Code of 1986 (26 U.S.C. 6621(a)(2)). 
In this action to collect overdue penalties, the court will not review 
the validity, amount, and appropriateness of the penalty.
    (2) In addition, if you do not pay the full amount of a penalty on 
time, you must then pay more to cover interest, enforcement expenses 
(including attorney's fees and costs for collection), and a quarterly 
nonpayment penalty for each quarter you do not pay. The quarterly 
nonpayment penalty is 10 percent of your total penalties plus any unpaid 
nonpayment penalties from previous quarters.

[73 FR 59344, Oct. 8, 2008, as amended at 75 FR 23062, Apr. 30, 2010; 81 
FR 74226, Oct. 25, 2016]



                   Subpart C_Exemptions and Exclusions



Sec.  1068.201  General exemption and exclusion provisions.

    We may exempt new engines/equipment from some or all of the 
prohibited acts or requirements of this part under provisions described 
in this subpart. We may exempt nonroad engines/equipment already placed 
in service in the United States from the prohibition in Sec.  
1068.101(b)(1) if the exemption for nonroad engines/equipment used 
solely for competition applies (see Sec.  1068.235). In addition, see 
Sec.  1068.1 and the standard-setting parts to determine if other 
engines/equipment are excluded from some or all of the regulations in 
this chapter.

[[Page 466]]

    (a) This subpart identifies which engines/equipment qualify for 
exemptions and what information we need. We may require more 
information.
    (b) If you violate any of the terms, conditions, instructions, or 
requirements to qualify for an exemption, we may void, revoke, or 
suspend the exemption.
    (c) If you use an exemption under this subpart, we may require you 
to add a permanent or removable label to your exempted engines/
equipment. You may ask us to modify these labeling requirements if it is 
appropriate for your engine/equipment.
    (d) If you produce engines/equipment we exempt under this subpart, 
we may require you to make and keep records, perform tests, make reports 
and provide information as needed to reasonably evaluate the validity of 
the exemption.
    (e) If you own or operate engines/equipment we exempt under this 
subpart, we may require you to provide information as needed to 
reasonably evaluate the validity of the exemption.
    (f) Subpart D of this part describes how we apply these exemptions 
to engines/equipment you import (or intend to import).
    (g) If you want to ask for an exemption or need more information, 
write to the Designated Compliance Officer.
    (h) You may ask us to modify the administrative requirements for the 
exemptions described in this subpart or in subpart D of this part. We 
may approve your request if we determine that such approval is 
consistent with the intent of this part. For example, waivable 
administrative requirements might include some reporting requirements, 
but would not include any eligibility requirements or use restrictions.
    (i) If you want to take an action with respect to an exempted or 
excluded engine/equipment that is prohibited by the exemption or 
exclusion, such as selling it, you need to certify the engine/equipment. 
We will issue a certificate of conformity if you send us an application 
for certification showing that you meet all the applicable requirements 
from the standard-setting part and pay the appropriate fee. 
Alternatively, we may allow you to include in an existing certified 
engine family those engines/equipment you modify (or otherwise 
demonstrate) to be identical to engines/equipment already covered by the 
certificate. We would base such an approval on our review of any 
appropriate documentation. These engines/equipment must have emission 
control information labels that accurately describe their status.

[73 FR 59344, Oct. 8, 2008, as amended at 74 FR 8428, Feb. 24, 2009; 81 
FR 74226, Oct. 25, 2016]



Sec.  1068.210  Exempting test engines/equipment.

    (a) We may exempt engines/equipment that you will use for research, 
investigations, studies, demonstrations, or training. Note that you are 
not required to get an exemption under this section for engines that are 
exempted under other provisions of this part, such as the manufacturer-
owned exemption in Sec.  1068.215.
    (b) Anyone may ask for a testing exemption.
    (c) If you are a certificate holder, you may request an exemption 
for engines/equipment you intend to include in a test program.
    (1) In your request, tell us the maximum number of engines/equipment 
involved and describe how you will make sure exempted engines/equipment 
are used only for this testing. For example, if the exemption will 
involve other companies using your engines/equipment, describe your 
plans to track individual units so you can properly report on their 
final disposition.
    (2) Give us the information described in paragraph (d) of this 
section if we ask for it.
    (d) If you are not a certificate holder, do all the following 
things:
    (1) Show that the proposed test program has a valid purpose under 
paragraph (a) of this section.
    (2) Show you need an exemption to achieve the purpose of the test 
program (time constraints may be a basis for needing an exemption, but 
the cost of certification alone is not).
    (3) Estimate the duration of the proposed test program and the 
number of engines/equipment involved.
    (4) Allow us to monitor the testing.

[[Page 467]]

    (5) Describe how you will ensure that you stay within this 
exemption's purposes. Address at least the following things:
    (i) The technical nature of the test.
    (ii) The test site.
    (iii) The duration and accumulated engine/equipment operation 
associated with the test.
    (iv) Ownership and control of the engines/equipment involved in the 
test.
    (v) The intended final disposition of the engines/equipment.
    (vi) How you will identify, record, and make available the engine/
equipment identification numbers.
    (vii) The means or procedure for recording test results.
    (e) If we approve your request for a testing exemption, we will send 
you a letter or a memorandum describing the basis and scope of the 
exemption. It will also include any necessary terms and conditions, 
which normally require you to do the following:
    (1) Stay within the scope of the exemption.
    (2) Create and maintain adequate records that we may inspect.
    (3) Add a permanent label to all engines/equipment exempted under 
this section, consistent with Sec.  1068.45, with at least the following 
items:
    (i) The label heading ``EMISSION CONTROL INFORMATION''.
    (ii) Your corporate name and trademark.
    (iii) Engine displacement, family identification, and model year of 
the engine/equipment (as applicable), or whom to contact for further 
information.
    (iv) The statement: ``THIS [engine, equipment, vehicle, etc.] IS 
EXEMPT UNDER 40 CFR 1068.210 OR 1068.215 FROM EMISSION STANDARDS AND 
RELATED REQUIREMENTS.''
    (4) Tell us when the test program is finished.
    (5) Tell us the final disposition of the engines/equipment.

[76 FR 57488, Sept. 15, 2011, as amended at 81 FR 74226, Oct. 25, 2016; 
88 FR 4716, Jan. 24, 2023]



Sec.  1068.215  Exempting manufacturer-owned engines/equipment.

    (a) You are eligible for this exemption for manufacturer-owned 
engines/equipment only if you are a certificate holder. Any engine for 
which you meet all applicable requirements under this section is exempt 
without request.
    (b) Engines/equipment may be exempt without a request if they are 
nonconforming engines/equipment under your ownership, possession, and 
control and you do not operate them for purposes other than to develop 
products, assess production methods, or promote your engines/equipment 
in the marketplace, or other purposes we approve. You may not loan, 
lease, sell, or use the engine/equipment to generate revenue, either by 
itself or for an engine installed in a piece of equipment, except as 
allowed by Sec.  1068.201(i). Note that this paragraph (b) does not 
prevent the sale or shipment of a partially complete engine to a 
secondary engine manufacturer that will meet the requirements of this 
paragraph (b). See Sec.  1068.262 for provisions related to shipping 
partially complete engines to secondary engine manufacturers.
    (c) To use this exemption, you must do three things:
    (1) Establish, maintain, and keep adequately organized and indexed 
information on all exempted engines/equipment, including the engine/
equipment identification number, the use of the engine/equipment on 
exempt status, and the final disposition of any engine/equipment removed 
from exempt status.
    (2) Let us access these records, as described in Sec.  1068.20.
    (3) Add a permanent label to all engines/equipment exempted under 
this section, consistent with Sec.  1068.45, with at least the following 
items:
    (i) The label heading ``EMISSION CONTROL INFORMATION''.
    (ii) Your corporate name and trademark.
    (iii) Family identification and model year of the engine/equipment 
(as applicable), or whom to contact for further information.
    (iv) The statement: ``THIS [engine, equipment, vehicle, etc.] IS 
EXEMPT UNDER 40 CFR 1068.210 OR 1068.215 FROM EMISSION STANDARDS AND 
RELATED REQUIREMENTS.''

[73 FR 59344, Oct. 8, 2008, as amended at 75 FR 23062, Apr. 30, 2010; 81 
FR 74226, Oct. 25, 2016]

[[Page 468]]



Sec.  1068.220  Exempting display engines/equipment.

    (a) Anyone may request an exemption for display engines/equipment.
    (b) Nonconforming display engines/equipment will be exempted if they 
are used for displays in the interest of a business or the general 
public. The exemption in this section does not apply to engines/
equipment displayed for any purpose we determine is inappropriate for a 
display exemption.
    (c) You may operate the exempted engine/equipment, but only if we 
approve specific operation that is part of the display, or is necessary 
for the display (possibly including operation that is indirectly 
necessary for the display). We may consider any relevant factor in our 
approval process, including the extent of the operation, the overall 
emission impact, and whether the engine/equipment meets emission 
requirements of another country.
    (d) You may sell or lease the exempted engine/equipment only with 
our advance approval.
    (e) To use this exemption, you must add a permanent label to all 
engines/equipment exempted under this section, consistent with Sec.  
1068.45, with at least the following items:
    (1) The label heading ``EMISSION CONTROL INFORMATION''.
    (2) Your corporate name and trademark.
    (3) Engine displacement, family identification, and model year of 
the engine/equipment (as applicable), or whom to contact for further 
information.
    (4) The statement: ``THIS [engine, equipment, vehicle, etc.] IS 
EXEMPT UNDER 40 CFR 1068.220 FROM EMISSION STANDARDS AND RELATED 
REQUIREMENTS.''
    (f) We may set other conditions for approval of this exemption.

[81 FR 74226, Oct. 25, 2016, as amended at 88 FR 4716, Jan. 24, 2023]



Sec.  1068.225  Exempting engines/equipment for national security.

    The standards and requirements of the standard-setting part and the 
prohibitions in Sec.  1068.101(a)(1) and (b) do not apply to engines 
exempted under this section.
    (a) An engine/equipment is exempt without a request if it will be 
owned by an agency of the Federal Government responsible for national 
defense and it meets at least one of the following criteria:
    (1) An engine is automatically exempt in cases where the equipment 
in which it will be installed has armor, permanently attached weaponry, 
or other substantial features typical of military combat. Similarly, 
equipment subject to equipment-based standards is automatically exempt 
if it has any of these same features.
    (2) In the case of marine vessels with compression-ignition engines, 
an engine is automatically exempt if the vessel in which it will be 
installed has specialized electronic warfare systems, unique stealth 
performance requirements, or unique combat maneuverability requirements.
    (3) Gas turbine engines installed in marine vessels are 
automatically exempt.
    (4) An engine/equipment is automatically exempt if it would need 
sulfur-sensitive technology to comply with emission standards, and it is 
intended to be used in areas outside the United States where ultra low-
sulfur fuel is unavailable.
    (b) For the circumstances described in paragraphs (a)(1) and (2) of 
this section, an engine/equipment is also exempt without a request if it 
will be used, but not owned, by an agency of the Federal Government 
responsible for national defense.
    (c) Manufacturers may produce and ship engines/equipment under an 
automatic exemption as described in paragraph (a) or (b) of this section 
if they receive a written request for such engines/equipment from the 
appropriate federal agency.
    (d) Manufacturers may request a national security exemption for 
engines/equipment not meeting the conditions of paragraphs (a) and (b) 
of this section as long as the request is endorsed by an agency of the 
Federal Government responsible for national defense. In your request, 
explain why you need the exemption.
    (e) Add a permanent label to all engines/equipment exempted under 
this

[[Page 469]]

section, consistent with Sec.  1068.45, with at least the following 
items:
    (1) The label heading ``EMISSION CONTROL INFORMATION''.
    (2) Your corporate name and trademark.
    (3) Engine displacement, family identification, and model year of 
the engine/equipment (as applicable), or whom to contact for further 
information.
    (4) The statement: ``THIS [engine, equipment, vehicle, etc.] HAS AN 
EXEMPTION FOR NATIONAL SECURITY UNDER 40 CFR 1068.225.''

[81 FR 74227, Oct. 25, 2016]



Sec.  1068.230  Exempting engines/equipment for export.

    The provisions of this section apply differently depending on the 
country to which the engines/equipment are being exported.
    (a) We will not exempt new engines/equipment if you export them to a 
country with emission standards identical to ours, in which case they 
must be covered by a certificate of conformity. Where we determine that 
such engines/equipment will not be placed into service in the United 
States, the following provisions apply for special export-only 
certification:
    (1) The engines/equipment must be covered by a certificate of 
conformity or equivalent approval issued by the destination country.
    (2) To get an export-only certificate of conformity, send the 
Designated Compliance Officer a request. We may require you to provide 
information such as documentation of the foreign certification and 
related test data.
    (3) No fees apply for export-only certification.
    (4) The engines/equipment must be labeled as specified in paragraph 
(d) of this section.
    (5) This export-only certificate is not considered a valid 
certificate of conformity with respect to the prohibition in Sec.  
1068.101(a)(1) for sale to ultimate purchasers in the United States. 
These engines/equipment also may not reenter the United States unless 
the regulations of this chapter otherwise allow it.
    (b) Engines/equipment exported to a country not covered by paragraph 
(a) of this section are exempt from the prohibited acts in this part 
without a request. If you produce exempt engines/equipment for export 
and any of them are sold or offered for sale to an ultimate purchaser in 
the United States, the exemption is automatically void for those 
engines/equipment, except as specified in Sec.  1068.201(i). You may 
operate engines/equipment in the United States only as needed to prepare 
and deliver them for export.
    (c) Except as specified in paragraph (d) of this section, label 
exempted engines/equipment (including shipping containers if the label 
on the engine/equipment will be obscured by the container) with a label 
showing that they are not certified for sale or use in the United 
States. This label may be permanent or removable. See Sec.  1068.45 for 
provisions related to the use of removable labels and applying labels to 
containers without labeling individual engines/equipment. The label must 
include your corporate name and trademark and the following statement: 
``THIS [engine, equipment, vehicle, etc.] IS SOLELY FOR EXPORT AND IS 
THEREFORE EXEMPT UNDER 40 CFR 1068.230 FROM U.S. EMISSION STANDARDS AND 
RELATED REQUIREMENTS.''
    (d) You must apply a permanent label as specified in this paragraph 
(d) for engines/equipment certified under paragraph (a) of this section. 
You may apply a permanent label as specified in this paragraph (d) 
instead of the label specified in paragraph (c) of this section for 
exempted engines/equipment. Add a permanent label meeting the 
requirements of the destination country and include in the bill of 
lading a statement that the engines/equipment must be exported to avoid 
violating EPA regulations. We may modify applicable labeling 
requirements to align with the labeling requirements that apply for the 
destination country.
    (e) We may set other reasonable conditions to ensure that engines/
equipment exempted under this section are not placed into service in the 
United States.
    (f) Exemptions under this section expire once engines are no longer 
in the United States. Therefore exemptions under this section do not 
allow engines

[[Page 470]]

to be imported back into the United States.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74227, Oct. 25, 2016]



Sec.  1068.235  Exempting nonroad engines/equipment
used solely for competition.

    The following provisions apply for nonroad engines/equipment, but 
not for motor vehicles or for stationary applications:
    (a) New nonroad engines/equipment you produce that are used solely 
for competition are excluded from emission standards. We may exempt 
(rather than exclude) new nonroad engines/equipment you produce that you 
intend to be used solely for competition, where we determine that such 
engines/equipment are unlikely to be used contrary to your intent. See 
the standard-setting parts for specific provisions where applicable. 
Note that the definitions in the standard-setting part may deem 
uncertified engines/equipment to be new upon importation.
    (b) If you modify any nonroad engines/equipment after they have been 
placed into service in the United States so they will be used solely for 
competition, they are exempt without request. This exemption applies 
only to the prohibitions in Sec.  1068.101(b)(1) and (2) and are valid 
only as long as the engine/equipment is used solely for competition. You 
may not use the provisions of this paragraph (b) to circumvent the 
requirements that apply to the sale of new competition engines under the 
standard-setting part.
    (c) If you modify any nonroad engines/equipment under paragraph (b) 
of this section, you must destroy the original emission labels. If you 
loan, lease, sell, or give any of these engines/equipment to someone 
else, you must tell the new owner (or operator, if applicable) in 
writing that they may be used only for competition.

[81 FR 74227, Oct. 25, 2016]



Sec.  1068.240  Exempting new replacement engines.

    The prohibitions in Sec.  1068.101(a)(1) do not apply to a new 
engine if it is exempt under this section as a replacement engine. For 
purposes of this section, a replacement engine is a new engine that is 
used to replace an engine that has already been placed into service 
(whether the previous engine is replaced in whole or in part with a new 
engine).
    (a) General provisions. You are eligible for the exemption for new 
replacement engines only if you are a certificate holder. Note that this 
exemption does not apply for locomotives (40 CFR 1033.601) and that 
unique provisions apply to marine compression-ignition engines (40 CFR 
1042.615).
    (1) Paragraphs (b) and (c) of this section describe different 
approaches for exempting new replacement engines where the engines are 
specially built to correspond to an engine model from an earlier model 
year that was subject to less stringent standards than those that apply 
for current production (or is no longer covered by a certificate of 
conformity). You must comply with the requirements of paragraph (b) of 
this section for any number of replacement engines you produce in excess 
of what we allow under paragraph (c) of this section. You must designate 
engines you produce under this section as tracked engines under 
paragraph (b) of this section or untracked engines under paragraph (c) 
of this section by the deadline for the report specified in paragraph 
(c)(3) of this section.
    (2) Paragraph (e) of this section describes a simpler approach for 
exempting partially complete new replacement engines that are built 
under a certificate of conformity that is valid for producing engines 
for the current model year.
    (3) For all the different approaches described in paragraphs (b) 
through (e) of this section, the exemption applies only for equipment 
that is 40 years old or less at the time of installation.
    (b) Previous-tier replacement engines with tracking. You may produce 
any number of new engines to replace an engine already placed into 
service in a piece of equipment, as follows:
    (1) The engine being replaced must have been either not originally 
subject to emission standards or originally subject to less stringent 
emission standards than those that apply to a new engine meeting current 
standards. The provisions of this paragraph (b)

[[Page 471]]

also apply for engines that were originally certified to the same 
standards that apply for the current model year if you no longer have a 
certificate of conformity to continue producing that engine 
configuration.
    (2) The following requirements and conditions apply for engines 
exempted under this paragraph (b):
    (i) You must determine that you do not produce an engine certified 
to meet current requirements that has the appropriate physical or 
performance characteristics to repower the equipment. If the engine 
being replaced was made by a different company, you must make this 
determination also for engines produced by this other company.
    (ii) In the case of premature engine failure, if the old engine was 
subject to emission standards, you must make the new replacement engine 
in a configuration identical in all material respects to the old engine 
and meet the requirements of Sec.  1068.265. You may alternatively make 
the new replacement engine in a configuration identical in all material 
respects to another certified engine of the same or later model year as 
long as the engine is not certified with a family emission limit higher 
than that of the old engine.
    (iii) For cases not involving premature engine failure, you must 
make a separate determination for your own product line addressing every 
tier of emission standards that is more stringent than the emission 
standards for the engine being replaced. For example, if the engine 
being replaced was built before the Tier 1 standards started to apply 
and engines of that power category are currently subject to Tier 3 
standards, you must also consider whether any Tier 1 or Tier 2 engines 
that you produce have the appropriate physical and performance 
characteristics for replacing the old engine; if you produce a Tier 2 
engine with the appropriate physical and performance characteristics, 
you must use it as the replacement engine.
    (iv) You must keep records to document your basis for making the 
determinations in paragraphs (b)(2)(i) and (iii) of this section.
    (3) An old engine block replaced by a new engine exempted under this 
paragraph (b) may be reintroduced into U.S. commerce as part of an 
engine that meets either the current standards for new engines, the 
provisions for new replacement engines in this section, or another valid 
exemption. Otherwise, you must destroy the old engine block (or confirm 
that it has been destroyed), or export the engine block without its 
emission label. Note that this paragraph (b)(3) does not require engine 
manufacturers to take possession of the engine being replaced. Owners 
may arrange to keep the old engine if they demonstrate that the engine 
block has been destroyed. An engine block is destroyed under this 
paragraph (b)(3) if it can never be restored to a running configuration.
    (4) If the old engine was subject to emission standards, the 
replacement engine must meet the appropriate emission standards as 
specified in Sec.  1068.265. This generally means you must make the new 
replacement engine in a previously certified configuration.
    (5) Except as specified in paragraph (d) of this section, you must 
add a permanent label, consistent with Sec.  1068.45, with your 
corporate name and trademark and the following additional information:
    (i) Add the following statement if the new engine may only be used 
to replace an engine that was not subject to any emission standards 
under this chapter:

    THIS REPLACEMENT ENGINE IS EXEMPT UNDER 40 CFR 1068.240. SELLING OR 
INSTALLING THIS ENGINE FOR ANY PURPOSE OTHER THAN TO REPLACE AN 
UNREGULATED ENGINE MAY BE A VIOLATION OF FEDERAL LAW SUBJECT TO CIVIL 
PENALTY. THIS ENGINE MAY NOT BE INSTALLED IN EQUIPMENT THAT IS MORE THAN 
40 YEARS OLD AT THE TIME OF INSTALLATION.

    (ii) Add the following statement if the new engine may replace an 
engine that was subject to emission standards:

    THIS ENGINE COMPLIES WITH U.S. EPA EMISSION REQUIREMENTS FOR 
[Identify the appropriate emission standards (by model year, tier, or 
emission levels) for the replaced engine] ENGINES UNDER 40 CFR 1068.240. 
SELLING OR INSTALLING THIS ENGINE FOR ANY PURPOSE OTHER THAN TO REPLACE 
A [Identify the appropriate emission standards for the replaced engine, 
by model year(s), tier(s), or emission levels)]

[[Page 472]]

ENGINE MAY BE A VIOLATION OF FEDERAL LAW SUBJECT TO CIVIL PENALTY. THIS 
ENGINE MAY NOT BE INSTALLED IN EQUIPMENT THAT IS MORE THAN 40 YEARS OLD 
AT THE TIME OF INSTALLATION.

    (6) Engines exempt under this paragraph (b) may not be introduced 
into U.S. commerce before you make the determinations under paragraph 
(b)(2) of this section, except as specified in this paragraph (b)(6). We 
may waive the restriction in this paragraph (b)(6) for engines 
identified under paragraph (c)(5) of this section that you ship to a 
distributor. Where we waive the restriction in this paragraph (b)(6), 
you must take steps to ensure that the engine is installed consistent 
with the requirements of this paragraph (b). For example, at a minimum 
you must report to us annually whether engines we allowed you to ship to 
a distributor under this paragraph (b)(6) have been placed into service 
or remain in inventory. After an engine is placed into service, your 
report must describe how the engine was installed consistent with the 
requirements of this paragraph (b). Send these reports to the Designated 
Compliance Officer by the deadlines we specify.
    (c) Previous-tier replacement engines without tracking. You may 
produce a limited number of new replacement engines that are not from a 
currently certified engine family under the provisions of this paragraph 
(c). If you produce new engines under this paragraph (c) to replace 
engines subject to emission standards, the new replacement engine must 
be in a configuration identical in all material respects to the old 
engine and meet the requirements of Sec.  1068.265. You may make the new 
replacement engine in a configuration identical in all material respects 
to another certified engine of the same or later model year as long as 
the engine is not certified with a family emission limit higher than 
that of the old engine. The provisions of this paragraph (c) also apply 
for engines that were originally certified to the same standards that 
apply for the current model year if you no longer have a certificate of 
conformity to continue producing that engine configuration. This would 
apply, for example, for engine configurations that were certified in an 
earlier model year but are no longer covered by a certificate of 
conformity. The following provisions apply to engines exempted under 
this paragraph (c):
    (1) You may produce a limited number of replacement engines under 
this paragraph (c) representing 0.5 percent of your annual production 
volumes for each category and subcategory of engines identified in Table 
1 to this section or five engines for each category and subcategory, 
whichever is greater. Calculate this number by multiplying your annual 
U.S.-directed production volume by 0.005 (or 0.01 through 2013) and 
rounding to the nearest whole number. Determine the appropriate 
production volume by identifying the highest total annual U.S.-directed 
production volume of engines from the previous three model years for all 
your certified engines from each category or subcategory identified in 
Table 1 to this section, as applicable. In unusual circumstances, you 
may ask us to base your production limits on U.S.-directed production 
volume for a model year more than three years prior. You may include 
stationary engines and exempted engines as part of your U.S.-directed 
production volume. Include U.S.-directed engines produced by any 
affiliated companies and those from any other companies you license to 
produce engines for you.
    (2) Count every exempted new replacement engine from your total 
U.S.-directed production volume that you produce in a given calendar 
year under this paragraph (c), including partially complete engines, 
except for the following:
    (i) Engines built to specifications for an earlier model year under 
paragraph (b) of this section.
    (ii) Partially complete engines exempted under paragraph (e) of this 
section.
    (3) Send the Designated Compliance Officer a report by September 30 
of the year following any year in which you produced exempted 
replacement engines under this paragraph (c).
    (i) In your report include the total number of replacement engines 
you produce under this paragraph (c) for each category or subcategory, 
as appropriate, and the corresponding total

[[Page 473]]

production volumes determined under paragraph (c)(1) of this section. If 
you send us a report under this paragraph (c)(3), you must also include 
the total number of complete and partially complete replacement engines 
you produced under paragraphs (b) and (e) of this section (including any 
replacement marine engines subject to reporting under 40 CFR 1042.615).
    (ii) Count exempt engines as tracked under paragraph (b) of this 
section only if you meet all the requirements and conditions that apply 
under paragraph (b)(2) of this section by the due date for the annual 
report. In the annual report you must identify any replaced engines from 
the previous year whose final disposition is not resolved by the due 
date for the annual report. Continue to report those engines in later 
reports until the final disposition is resolved. If the final 
disposition of any replaced engine is not resolved for the fifth annual 
report following the production report, treat this as an untracked 
replacement in the fifth annual report for the preceding year.
    (iii) You may include the information required under this paragraph 
(c)(3) in production reports required under the standard-setting part.
    (4) Add a permanent label as specified in paragraph (b)(5) of this 
section. For partially complete engines, you may alternatively add a 
permanent or removable label as specified in paragraph (d) of this 
section.
    (5) You may not use the provisions of this paragraph (c) for any 
engines in the following engine categories or subcategories:
    (i) Land-based nonroad compression-ignition engines we regulate 
under 40 CFR part 1039 with a per-cylinder displacement at or above 7.0 
liters.
    (ii) Marine compression-ignition engines we regulate under 40 CFR 
part 1042 with a per-cylinder displacement at or above 7.0 liters.
    (iii) Locomotive engines we regulate under 40 CFR part 1033.
    (d) Partially complete engines. The following requirements apply if 
you ship a partially complete replacement engine under this section:
    (1) Provide instructions specifying how to complete the engine 
assembly such that the resulting engine conforms to the applicable 
certificate of conformity or the specifications of Sec.  1068.265. Where 
a partially complete engine can be built into multiple different 
configurations, you must be able to identify all the engine models and 
model years for which the partially complete engine may properly be used 
for replacement purposes. Your instructions must make clear how the 
final assembler can determine which configurations are appropriate for 
the engine they receive.
    (2) You must label the engine as follows:
    (i) If you have a reasonable basis to believe that the fully 
assembled engine will include the original emission control information 
label, you may add a removable label to the engine with your corporate 
name and trademark and the statement: ``This replacement engine is 
exempt under 40 CFR 1068.240.'' This would generally apply if all the 
engine models that are compatible with the replacement engine were 
covered by a certificate of conformity and they were labeled in a 
position on the engine or equipment that is not included as part of the 
partially complete engine being shipped for replacement purposes. 
Removable labels must meet the requirements specified in Sec.  1068.45.
    (ii) If you do not qualify for using a removable label in paragraph 
(d)(2)(i) of this section, you must add a permanent label in a readily 
visible location, though it may be obscured after installation in a 
piece of equipment. Include on the permanent label your corporate name 
and trademark, the engine's part number (or other identifying 
information), and the statement: ``THIS REPLACEMENT ENGINE IS EXEMPT 
UNDER 40 CFR 1068.240. THIS ENGINE MAY NOT BE INSTALLED IN EQUIPMENT 
THAT IS MORE THAN 40 YEARS OLD AT THE TIME OF INSTALLATION.'' If there 
is not enough space for this statement, you may alternatively add: 
``REPLACEMENT'' or ``SERVICE ENGINE.'' For purposes of this paragraph 
(d)(2), engine part numbers permanently stamped or engraved on the 
engine are considered to be included on the label.
    (e) Partially complete current-tier replacement engines. The 
provisions of

[[Page 474]]

paragraph (d) of this section apply for engines you produce from a 
current line of certified engines or vehicles if you ship them as 
partially complete engines for replacement purposes. This applies for 
engine-based and equipment-based standards as follows:
    (1) Where engine-based standards apply, you may introduce into U.S. 
commerce short blocks or other partially complete engines from a 
currently certified engine family as replacement components for in-use 
equipment powered by engines you originally produced. You must be able 
to identify all the engine models and model years for which the 
partially complete engine may properly be used for replacement purposes.
    (2) Where equipment-based standards apply, you may introduce into 
U.S. commerce engines that are identical to engines covered by a current 
certificate of conformity by demonstrating compliance with currently 
applicable standards where the engines will be installed as replacement 
engines. These engines might be fully assembled, but we would consider 
them to be partially complete engines because they are not yet installed 
in the equipment.
    (f) Emission credits. Replacement engines exempted under this 
section may not generate or use emission credits under the standard-
setting part nor be part of any associated credit calculations.

 Table 1 to Sec.   1068.240--Engine Categories and Subcategories for New
              Replacement Engines Exempted Without Tracking
------------------------------------------------------------------------
                                   Standard-setting         Engine
         Engine category               part \1\          subcategories
------------------------------------------------------------------------
Highway CI......................  40 CFR part 86....  disp. < 0.6 L/cyl.
                                                      0.6 <= disp. < 1.2
                                                       L/cyl.
                                                      disp. =
                                                       1.2 L/cyl.
Nonroad CI, Stationary CI, and    40 CFR part 1039,   disp. < 0.6 L/cyl.
 Marine CI.                        or 40 CFR part     0.6 <= disp. < 1.2
                                   1042.               L/cyl.
                                                      1.2 <= disp. < 2.5
                                                       L/cyl.
                                                      2.5 <= disp. < 7.0
                                                       L/cyl.
Marine SI.......................  40 CFR part 1045..  outboard.
                                                      personal
                                                       watercraft.
Large SI, Stationary SI, and      40 CFR part 1048    all engines.
 Marine SI (sterndrive/inboard     or 40 CFR part
 only).                            1045.
Recreational vehicles...........  40 CFR part 1051..  off-highway
                                                       motorcycle.
                                                      all-terrain
                                                       vehicle.
                                                      snowmobile.
Small SI and Stationary SI......  40 CFR part 1054..  handheld.
                                                      Class I.
                                                      Class II.
------------------------------------------------------------------------
\1\ Include an engine as being subject to the identified standard-
  setting part if it will eventually be subject to emission standards
  under that part. For example, if you certify marine compression-
  ignition engines under part 94, count those as if they were already
  subject to part 1042.


[79 FR 7085, Feb. 6, 2014, as amended at 81 FR 74227, Oct. 25, 2016; 86 
FR 34589, June 29, 2021; 88 FR 4716, Jan. 24, 2023]



Sec.  1068.245  Temporary provisions addressing hardship due 
to unusual circumstances.

    (a) After considering the circumstances, we may permit you to 
introduce into U.S. commerce engines/equipment that do not comply with 
emission-related requirements for a limited time if all the following 
conditions apply:
    (1) Unusual circumstances that are clearly outside your control 
prevent you from meeting requirements from this chapter.
    (2) You exercised prudent planning and were not able to avoid the 
violation; you have taken all reasonable steps to minimize the extent of 
the nonconformity.
    (3) No other allowances are available under the regulations in this 
chapter to avoid the impending violation, including the provisions of 
Sec.  1068.250.
    (4) Not having the exemption will jeopardize the solvency of your 
company.
    (b) If your unusual circumstances are only related to compliance 
with the model-year provisions of Sec.  1068.103(f), we may grant 
hardship under this section without a demonstration that the

[[Page 475]]

solvency of your company is in jeopardy as follows:
    (1) You must demonstrate that the conditions specified in paragraphs 
(a)(1) through (3) of this section apply.
    (2) Your engines/equipment must comply with standards and other 
requirements that would have applied if assembly were completed on 
schedule.
    (3) You may generally request this exemption only for engines/
equipment for which assembly has been substantially completed; you may 
not begin assembly of any additional engines/equipment under this 
exemption after the cause for delay has occurred. We may make an 
exception to this general restriction for secondary engine 
manufacturers.
    (4) As an example, if your normal production process involves 
purchase of partially complete engines and a supplier fails to deliver 
all the ordered engines in time for your assembly according to your 
previously established schedule as a result of a fire at its factory, 
you may request that we treat those engine as if they had been completed 
on the original schedule. Note that we would grant relief only for those 
engines where you had a reasonable basis for expecting the engines to be 
delivered on time based on past performance and terms of purchase.
    (c) To apply for an exemption, you must send the Designated 
Compliance Officer a written request as soon as possible before you are 
in violation. In your request, show that you meet all the conditions and 
requirements in paragraph (a) of this section.
    (d) Include in your request a plan showing how you will meet all the 
applicable requirements as quickly as possible.
    (e) You must give us other relevant information if we ask for it.
    (f) We may include reasonable additional conditions on an approval 
granted under this section, including provisions to recover or otherwise 
address the lost environmental benefit or paying fees to offset any 
economic gain resulting from the exemption. For example, in the case of 
multiple tiers of emission standards, we may require that you meet the 
standards from the previous tier whether or not your hardship is granted 
under paragraph (b) of this section.
    (g) Add a permanent label to all engines/equipment exempted under 
this section, consistent with Sec.  1068.45, with at least the following 
items:
    (1) The label heading ``EMISSION CONTROL INFORMATION''.
    (2) Your corporate name and trademark.
    (3) Engine displacement (in liters or cubic centimeters), and model 
year of the engine/equipment, (as applicable); or whom to contact for 
further information. We may also require that you include maximum engine 
power.
    (4) A statement describing the engine's status as an exempted 
engine:
    (i) If the engine/equipment does not meet any emission standards, 
add the following statement: ``THIS [engine, equipment, vehicle, etc.] 
IS EXEMPT UNDER 40 CFR 1068.245 FROM EMISSION STANDARDS AND RELATED 
REQUIREMENTS.''
    (ii) If the engines/equipment meet alternate emission standards as a 
condition of an exemption under this section, we may specify a different 
statement to identify the alternate emission standards.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74228, Oct. 25, 2016]



Sec.  1068.250  Extending compliance deadlines for small businesses
under hardship.

    (a) After considering the circumstances, we may extend the 
compliance deadline for you to meet new or revised emission standards as 
long as you meet all the conditions and requirements in this section.
    (b) You must be a small business to be eligible for this exemption.
    (c) Send the Designated Compliance Officer a written request for an 
extension as soon as possible before you are in violation. In your 
request, show that all the following conditions and requirements apply:
    (1) You have taken all possible business, technical, and economic 
steps to comply.
    (i) In the case of importers of engines/equipment produced by other 
companies, show that you attempted to find a manufacturer capable of 
supplying complying products as soon as

[[Page 476]]

you became aware of the applicable requirements but were unable to do 
so.
    (ii) For all other manufacturers, show that the burden of compliance 
costs prevents you from meeting the requirements of this chapter.
    (2) Not having the exemption will jeopardize the solvency of your 
company.
    (3) No other allowances are available under the regulations in this 
chapter to avoid the impending violation.
    (d) In describing the steps you have taken to comply under paragraph 
(c)(1) of this section, include at least the following information:
    (1) Describe your business plan, showing the range of projects 
active or under consideration.
    (2) Describe your current and projected financial status, with and 
without the burden of complying fully with the applicable regulations in 
this chapter.
    (3) Describe your efforts to raise capital to comply with 
regulations in this chapter (this may not apply for importers).
    (4) Identify the engineering and technical steps you have taken or 
those you plan to take to comply with regulations in this chapter.
    (5) Identify the level of compliance you can achieve. For example, 
you may be able to produce engines/equipment that meet a somewhat less 
stringent emission standard than the regulations in this chapter 
require.
    (e) Include in your request a plan showing how you will meet all the 
applicable requirements as quickly as possible.
    (f) You must give us other relevant information if we ask for it.
    (g) An authorized representative of your company must sign the 
request and include the statement: ``All the information in this request 
is true and accurate to the best of my knowledge.''
    (h) [Reserved]
    (j) We may approve extensions of the compliance deadlines as 
reasonable under the circumstances up to one model year at a time, and 
up to three years total.
    (k) Add a permanent label to all engines/equipment exempted under 
this section, consistent with Sec.  1068.45, with at least the following 
items:
    (1) The label heading ``EMISSION CONTROL INFORMATION''.
    (2) Your corporate name and trademark.
    (3) Engine displacement (in liters or cubic centimeters), and model 
year of the engine/equipment (as applicable); or whom to contact for 
further information. We may also require that you include maximum engine 
power.
    (4) A statement describing the engine's status as an exempted 
engine:
    (i) If the engine/equipment does not meet any emission standards, 
add the following statement:``THIS [engine, equipment, vehicle, etc.] IS 
EXEMPT UNDER 40 CFR 1068.250 FROM EMISSION STANDARDS AND RELATED 
REQUIREMENTS.''
    (ii) If the engine/equipment meets alternate emission standards as a 
condition of an exemption under this section, we may specify a different 
statement to identify the alternate emission standards.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74228, Oct. 25, 2016]



Sec.  1068.255  Exempting engines and fuel-system components for
hardship for equipment manufacturers and secondary engine manufacturers.

    This section describes how, in unusual circumstances, we may approve 
an exemption to prevent hardship to an equipment manufacturer or a 
secondary engine manufacturer. This section does not apply to products 
that are subject to equipment-based exhaust emission standards.
    (a) Equipment exemption. As an equipment manufacturer, you may ask 
for approval to produce exempted equipment for up to 12 months. We will 
generally limit this to a single interval up to 12 months in the first 
year that new or revised emission standards apply. Exemptions under this 
section are not limited to small businesses. Send the Designated 
Compliance Officer a written request for an exemption before you are in 
violation. In your request, you must show you are not at fault for the 
impending violation and that you would face serious economic hardship if 
we do not grant the exemption. This exemption is not available under 
this paragraph (a) if you manufacture the engine or fuel-system 
components you

[[Page 477]]

need for your own equipment, or if complying engines or fuel-system 
components are available from other manufacturers that could be used in 
your equipment, unless we allow it elsewhere in this chapter. We may 
impose other conditions, including provisions to use products meeting 
less stringent emission standards or to recover the lost environmental 
benefit. In determining whether to grant the exemptions, we will 
consider all relevant factors, including the following:
    (1) The number of engines or fuel-system components involved.
    (2) The size of your company and your ability to endure the 
hardship.
    (3) The amount of time you had to redesign your equipment to 
accommodate complying products.
    (4) Whether there was any breach of contract by a supplier.
    (5) The potential for market disruption.
    (b) Engine and fuel-system component exemption. As an engine 
manufacturer or fuel-system component manufacturer, you may produce 
nonconforming products for the equipment we exempt in paragraph (a) of 
this section. You do not have to request this exemption but you must 
have written assurance from equipment manufacturers that they need a 
certain number of exempted products under this section. Label engines or 
fuel-system components as follows, consistent with Sec.  1068.45:
    (1) Engines. Add a permanent label to all engines/equipment exempted 
under this section with at least the following items:
    (i) The label heading ``EMISSION CONTROL INFORMATION''.
    (ii) Your corporate name and trademark.
    (iii) Engine displacement (in liters or cubic centimeters) and model 
year of the engine, or whom to contact for further information. We may 
also require that you include maximum engine power.
    (iv) If the engine does not meet any emission standards: ``THIS 
ENGINE IS EXEMPT UNDER 40 CFR 1068.255 FROM EMISSION STANDARDS AND 
RELATED REQUIREMENTS.'' If the engine meets alternate emission standards 
as a condition of an exemption under this section, we may specify a 
different statement to identify the alternate emission standards.
    (2) Fuel-system components. Add a permanent label to all engines/
equipment exempted under this section with at least the following items:
    (i) Your corporate name and trademark.
    (ii) The statement ``EXEMPT UNDER 40 CFR 1068.255''.
    (c) Secondary engine manufacturers. As a secondary engine 
manufacturer, you may ask for approval to produce exempted engines under 
this section for up to 12 months. We may require you to certify your 
engines to compliance levels above the emission standards that apply. 
For example, in the case of multiple tiers of emission standards, we may 
require you to meet the standards from the previous tier.
    (1) The provisions in paragraph (a) of this section that apply to 
equipment manufacturers requesting an exemption apply equally to you 
except that you may manufacture the engines. Before we approve an 
exemption under this section, we will generally require that you commit 
to a plan to make up the lost environmental benefit.
    (i) If you produce uncertified engines under this exemption, we will 
calculate the lost environmental benefit based on our best estimate of 
uncontrolled emission rates for your engines.
    (ii) If you produce engines under this exemption that are certified 
to a compliance level less stringent than the emission standards that 
would otherwise apply, we will calculate the lost environmental benefit 
based on the compliance level you select for your engines.
    (2) The labeling requirements in paragraph (b) of this section apply 
to your exempted engines; however, if you certify engines to specific 
compliance levels, state on the label the compliance levels that apply 
to each engine.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74228, Oct. 25, 2016]



Sec.  1068.260  General provisions for selling or shipping engines
that are not yet in their certified configuration.

    Except as specified in paragraph (e) of this section, all new 
engines in the United States are presumed to be subject to the 
prohibitions of Sec.  1068.101,

[[Page 478]]

which generally require that all new engines be in a certified 
configuration before being sold, offered for sale, or introduced or 
delivered into commerce in the United States or imported into the United 
States. All emission-related components generally need to be installed 
on an engine for such an engine to be in its certified configuration. 
This section specifies clarifications and exemptions related to these 
requirements for engines. Except for paragraph (c) of this section, the 
provisions of this section generally apply for engine-based standards 
but not for equipment-based exhaust emission standards.
    (a) The provisions of this paragraph (a) apply for emission-related 
components that cannot practically be assembled before shipment because 
they depend on equipment design parameters.
    (1) You do not need an exemption to ship an engine that does not 
include installation or assembly of certain emission-related components 
if those components are shipped along with the engine. For example, you 
may generally ship aftertreatment devices along with engines rather than 
installing them on the engine before shipment. We may require you to 
describe how you plan to use this provision.
    (2) You may ask us at the time of certification for an exemption to 
allow you to ship your engines without emission-related components. If 
we allow this, we may specify conditions that we determine are needed to 
ensure that shipping the engine without such components will not result 
in the engine being operated outside of its certified configuration. You 
must identify unshipped parts by specific part numbers if they cannot be 
properly characterized by performance specification. For example, 
electronic control units, turbochargers, and EGR coolers must generally 
be identified by part number. Parts that we believe can be properly 
characterized by performance specification include air filters, 
noncatalyzed mufflers, and charge air coolers. See paragraph (d) of this 
section for additional provisions that apply in certain circumstances.
    (b) You do not need an exemption to ship engines without specific 
components if they are not emission-related components identified in 
Appendix I of this part. For example, you may generally ship engines 
without the following parts:
    (1) Radiators needed to cool the engine.
    (2) Exhaust piping between the engine and an aftertreatment device, 
between two aftertreatment devices, or downstream of the last 
aftertreatment device.
    (c) If you are a certificate holder, partially complete engines/
equipment shipped between two of your facilities are exempt, subject to 
the provisions of this paragraph (c), as long as you maintain ownership 
and control of the engines/equipment until they reach their destination. 
We may also allow this where you do not maintain actual ownership and 
control of the engines/equipment (such as hiring a shipping company to 
transport the engines) but only if you demonstrate that the engines/
equipment will be transported only according to your specifications. See 
Sec.  1068.261(b) for the provisions that apply instead of this 
paragraph (c) for the special case of integrated manufacturers using the 
delegated-assembly exemption. Notify us of your intent to use this 
exemption in your application for certification, if applicable. Your 
exemption is effective when we grant your certificate. You may 
alternatively request an exemption in a separate submission; for 
example, this would be necessary if you will not be the certificate 
holder for the engines in question. We may require you to take specific 
steps to ensure that such engines/equipment are in a certified 
configuration before reaching the ultimate purchaser. Note that since 
this is a temporary exemption, it does not allow you to sell or 
otherwise distribute to ultimate purchasers an engine/equipment in an 
uncertified configuration with respect to exhaust emissions. Note also 
that the exempted engine/equipment remains new and subject to emission 
standards (see definition of ``exempted'' in Sec.  1068.30) until its 
title is transferred to the ultimate purchaser or it otherwise ceases to 
be new.
    (d) See Sec.  1068.261 for delegated-assembly provisions in which 
certificate-holding manufacturers ship engines

[[Page 479]]

that are not yet equipped with certain emission-related components. See 
Sec.  1068.262 for provisions related to manufacturers shipping 
partially complete engines for which a secondary engine manufacturer 
holds the certificate of conformity.
    (e) Engines used in hobby vehicles are not presumed to be engines 
subject to the prohibitions of Sec.  1068.101. Hobby vehicles are 
reduced-scale models of vehicles that are not capable of transporting a 
person. Some gas turbine engines are subject to the prohibitions of 
Sec.  1068.101, but we do not presume that all gas turbine engines are 
subject to these prohibitions. Other engines that do not have a valid 
certificate of conformity or exemption when sold, offered for sale, or 
introduced or delivered into commerce in the United States or imported 
into the United States are presumed to be engines subject to the 
prohibitions of Sec.  1068.101 unless we determine that such engines are 
excluded from the prohibitions of Sec.  1068.101.
    (f) While we presume that new non-hobby engines are subject to the 
prohibitions of Sec.  1068.101, we may determine that a specific engine 
is not subject to these prohibitions based on information you provide or 
other information that is available to us. For example, the provisions 
of this part 1068 and the standard-setting parts provide for exemptions 
in certain circumstances. Also, some engines may be subject to separate 
prohibitions under subchapter C instead of the prohibitions of Sec.  
1068.101.

[81 FR 74228, Oct. 25, 2016]



Sec.  1068.261  Delegated assembly and other provisions related 
to engines not yet in the certified configuration.

    This section describes an exemption that allows certificate holders 
to sell or ship engines that are missing certain emission-related 
components if those components will be installed by an equipment 
manufacturer. This section does not apply to equipment subject to 
equipment-based standards. See the standard-setting part to determine 
whether and how the provisions of this section apply. (Note: See Sec.  
1068.262 for provisions related to manufacturers introducing into U.S. 
commerce partially complete engines for which someone else holds the 
certificate of conformity.) This exemption is temporary as described in 
paragraph (f) of this section.
    (a) Shipping an engine separately from an aftertreatment component 
that you have specified as part of its certified configuration will not 
be a violation of the prohibitions in Sec.  1068.101(a)(1) subject to 
the provisions in this section. We may also require that you apply some 
or all of the provisions of this section for other components if we 
determine it is necessary to ensure that shipping the engine without 
such components will not result in the engine being operated outside of 
its certified configuration. In making this determination, we will 
consider the importance of the component for controlling emissions and 
the likelihood that equipment manufacturers will have an incentive to 
disregard your emission-related installation instructions based on any 
relevant factors, such as the cost of the component and any real or 
perceived expectation of a negative impact on engine or equipment 
performance.
    (b) If you manufacture engines and install them in equipment you or 
an affiliated company also produce, you must take steps to ensure that 
your facilities, procedures, and production records are set up to ensure 
that equipment and engines are assembled in their proper certified 
configurations. For example, you may demonstrate compliance with the 
requirements of this section by maintaining a database showing how you 
pair aftertreatment components with the appropriate engines such that 
the final product is in its certified configuration.
    (c) If you manufacture engines and ship them to an unaffiliated 
company for installation in equipment and you include the price of all 
aftertreatment components in the price of the engine (whether or not you 
ship the aftertreatment components directly to the equipment 
manufacturer), all the following conditions apply:
    (1) Apply for and receive a certificate of conformity for the engine 
and its

[[Page 480]]

emission control system before shipment as described in the standard-
setting part. For an existing certificate of conformity, amend the 
application for certification by describing your plans to use the 
provisions of this section as described in paragraph (c)(8) of this 
section.
    (2) Provide installation instructions in enough detail to ensure 
that the engine will be in its certified configuration if someone 
follows these instructions. Provide the installation instructions in a 
timely manner, generally directly after you receive an order for 
shipping engines or earlier. If you apply removable labels as described 
in paragraph (c)(7)(i) of this section, include an instruction for the 
equipment manufacturer to remove the label after installing the 
appropriate aftertreatment component.
    (3) Have a contractual agreement with the equipment manufacturer 
obligating the equipment manufacturer to complete the final assembly of 
the engine so it is in its certified configuration when final assembly 
is complete. This agreement must also obligate the equipment 
manufacturer to provide the affidavits required under paragraph (c)(4) 
of this section.
    (4) Take appropriate additional steps to ensure that all engines 
will be in a certified configuration when installed by the equipment 
manufacturer. At a minimum, you must obtain annual affidavits from every 
equipment manufacturer to which you sell engines under this section. 
Include engines that you sell to distributors or dealers. The affidavits 
must list the part numbers of the aftertreatment devices that equipment 
manufacturers install on each engine they purchase from you under this 
section and include confirmation that the number of aftertreatment 
devices received were sufficient for the number of engines involved.
    (5) [Reserved]
    (6) Keep records to document how many engines you produce under this 
exemption. Also, keep records to document your contractual agreements 
under paragraph (c)(3) of this section. Keep all these records for five 
years after the end of the applicable model year and make them available 
to us upon request.
    (7) Make sure the engine has the emission control information label 
we require under the standard-setting part. Include additional labeling 
using one of the following approaches:
    (i) Apply an additional removable label in a way that makes it 
unlikely that the engine will be installed in equipment other than in 
its certified configuration. The label must identify the engine as 
incomplete and include a clear statement that failing to install the 
aftertreatment device, or otherwise failing to bring the engine into its 
certified configuration, is a violation of federal law subject to civil 
penalty.
    (ii) Add the statement ``DELEGATED ASSEMBLY'' to the permanent 
emission control information label. You may alternatively add the 
abbreviated statement ``DEL ASSY'' if there is not enough room on the 
label.
    (8) Describe the following things in your application for 
certification:
    (i) How you plan to use the provisions of this section.
    (ii) A detailed plan for auditing equipment manufacturers, as 
described in paragraph (d)(3) of this section, if applicable.
    (iii) All other steps you plan to take under paragraph (c)(4) of 
this section.
    (9) If one of your engines produced under this section is selected 
for production-line testing or a selective enforcement audit, you must 
arrange to get a randomly selected aftertreatment component from either 
the equipment manufacturer or the equipment manufacturer's supplier. You 
may keep an inventory of these randomly selected parts, consistent with 
good engineering judgment and the intent of this section. You may obtain 
such aftertreatment components from any point in the normal distribution 
from the aftertreatment component manufacturer to the equipment 
manufacturer. Keep records describing how you randomly selected these 
aftertreatment components, consistent with the requirements specified in 
the standard-setting part.
    (10) Note that for purposes of importation, you may itemize your 
invoice to identify separate costs for engines and aftertreatment 
components that will be shipped separately. A copy of your invoice from 
the aftertreatment

[[Page 481]]

manufacturer may be needed to avoid payment of importation duties for 
the engine that also include the value of aftertreatment components.
    (d) If you manufacture engines and ship them to an unaffiliated 
company for installation in equipment, but you do not include the price 
of all aftertreatment components in the price of the engine, you must 
meet all the conditions described in paragraphs (c)(1) through (9) of 
this section, with the following additional provisions:
    (1) The contractual agreement described in paragraph (c)(3) of this 
section must include a commitment that the equipment manufacturer will 
do the following things:
    (i) Purchase the aftertreatment components you have specified in 
your application for certification and keep records to document these 
purchases.
    (ii) Cooperate with the audits described in paragraph (d)(3) of this 
section.
    (2) You must have written confirmation that the equipment 
manufacturer has ordered the appropriate type of aftertreatment 
components for an initial shipment of engines under this section. For 
the purpose of this paragraph (d)(2), initial shipment means the first 
shipment of engines that are subject to new or more stringent emissions 
standard (or the first shipment of engines using the provisions of this 
section) to a given equipment manufacturer for a given engine family. 
For the purpose of this paragraph (d)(2), you may treat as a single 
engine family those engine families from different model years that 
differ only with respect to model year or other characteristics 
unrelated to emissions. You must receive the written confirmation within 
30 days after shipment. If you do not receive written confirmation 
within 30 days, you may not ship any more engines from that engine 
family to that equipment manufacturer until you have the written 
confirmation. Note that it may be appropriate to obtain subsequent 
written confirmations to ensure compliance with this section, as 
described in paragraph (c)(4) of this section.
    (3) You must perform or arrange for audits of equipment 
manufacturers as follows:
    (i) If you sell engines to 16 or more equipment manufacturers under 
the provisions of this section, you must annually perform or arrange for 
audits of four equipment manufacturers to whom you sell engines under 
this section. To select individual equipment manufacturers, divide all 
the affected equipment manufacturers into quartiles based on the number 
of engines they buy from you; select a single equipment manufacturer 
from each quartile each model year. Vary the equipment manufacturers 
selected for auditing from year to year, though you may repeat an audit 
in a later model year if you find or suspect that a particular equipment 
manufacturer is not properly installing aftertreatment devices.
    (ii) If you sell engines to fewer than 16 equipment manufacturers 
under the provisions of this section, set up a plan to perform or 
arrange for audits of each equipment manufacturer on average once every 
four model years.
    (iii) Starting with the 2019 model year, if you sell engines to 
fewer than 40 equipment manufacturers under the provisions of this 
section, you may ask us to approve a reduced auditing rate. We may 
approve an alternate plan that involves audits of each equipment 
manufacturer on average once every ten model years as long as you show 
that you have met the auditing requirements in preceding years without 
finding noncompliance or improper procedures.
    (iv) To meet these audit requirements, you or your agent must at a 
minimum inspect the assembling companies' procedures and production 
records to monitor their compliance with your instructions, investigate 
some assembled engines, and confirm that the number of aftertreatment 
devices shipped were sufficient for the number of engines produced.
    (v) You must keep records of these audits for five years after the 
end of the applicable model year.
    (e) The following provisions apply if you ship engines without air 
filters or other portions of the air intake system that are specifically 
identified by part number (or other specific part reference) in the 
application for certification such that the shipped engine is

[[Page 482]]

not in its certified configuration. You do not need an exemption under 
this section to ship engines without air intake system components if you 
instead describe in your installation instructions how equipment 
manufacturers should use components meeting certain functional 
specifications.
    (1) If you are using the provisions of this section to ship an 
engine without aftertreatment, apply all the provisions of this section 
to ensure that each engine, including its intake system, is in its 
certified configuration before it reaches the ultimate purchaser.
    (2) If you are not using the provisions of this section to ship an 
engine without aftertreatment, shipping an engine without air-intake 
components that you have specified as part of its certified 
configuration will not be a violation of the prohibitions in Sec.  
1068.101(a) if you follow the provisions specified in paragraph (b) or 
paragraphs (c)(1) through (9) of this section. If we find there is a 
problem, we may require you to perform audits as specified in paragraph 
(d)(3) of this section.
    (f) Once the equipment manufacturer takes possession of an engine 
exempted under this section and the engine reaches the point of final 
equipment assembly, the exemption expires and the engine is subject to 
all the prohibitions in Sec.  1068.101. Note that the engine's model 
year does not change based on the date the equipment manufacturer adds 
the aftertreatment device and/or air filter under this section.
    (g) You may use the provisions of this section for engines you sell 
to a distributor as described in this paragraph (g) using one of the 
following approaches:
    (1) You may sell engines through a distributor if you comply with 
the provisions of paragraph (d) of this section with respect to the 
equipment manufacturer.
    (2) You may treat the distributor as the equipment manufacturer as 
described in this paragraph (g)(2) for all applicable requirements and 
prohibitions. Such distributors must bring engines into their final 
certified configuration. This may include shipping the engine with the 
appropriate aftertreatment device and/or air filter, but without 
completing the assembly with all the components. The exemptions expire 
for such engines when the distributor no longer has control of them.
    (h) You must notify us within 15 days if you find from an audit or 
another source that engines produced under this section are not in a 
certified configuration at the point of final assembly or that an 
equipment manufacturer has otherwise failed to meet its obligations 
under this section. If this occurs, send us a report describing the 
circumstances related to the noncompliance within 75 days after you 
notify us.
    (i) We may suspend, revoke, or void an exemption under this section, 
as follows:
    (1) We may suspend or revoke your exemption for a specific equipment 
manufacturer if any of the engines are not in a certified configuration 
after installation in that manufacturer's equipment, or if we determine 
that the equipment manufacturer has otherwise failed to comply with the 
requirements of this section. We may also suspend or revoke your 
exemption for other engine families with respect to the equipment 
manufacturer unless you demonstrate that the noncompliance is limited to 
a specific engine family. You may not use this exemption for future 
shipments to the affected equipment manufacturer without taking action 
beyond the minimum steps specified in this section, such as performing 
on-site audits. We will approve further use of this exemption only if 
you convince us that you have adequately addressed the factors causing 
the noncompliance.
    (2) We may suspend or revoke your exemption for the entire engine 
family if we determine that you have failed to comply with the 
requirements of this section. If we make an adverse decision with 
respect to the exemption for any of your engine families under this 
paragraph (i), this exemption will not apply for future certificates 
unless you convince us that the factors causing the noncompliance do not 
apply to the other engine families. We may also set additional 
conditions beyond the provisions specified in this section.

[[Page 483]]

    (3) We may void your exemption for the entire engine family if you 
intentionally submit false or incomplete information or fail to keep and 
provide to EPA the records required by this section. Note that all 
records and reports required under this section (whether generated by 
the engine manufacturer, equipment manufacturer, or others) are subject 
to the prohibition in Sec.  1068.101(a)(2), which prohibits the 
submission of false or incomplete information. For example, the 
affidavits required by this section are considered a submission.
    (j) You are liable for the in-use compliance of any engine that is 
exempt under this section.
    (k) It is a violation of Sec.  1068.101(a)(1) for any person to 
introduce into U.S. commerce a previously exempted engine, including as 
part of a piece of equipment, without complying fully with the 
installation instructions.

[73 FR 59344, Oct. 8, 2008, as amended at 75 FR 23064, Apr. 30, 2010; 81 
FR 74229, Oct. 25, 2016; 88 FR 4716, Jan. 24, 2023]



Sec.  1068.262  Shipment of engines to secondary engine manufacturers.

    This section specifies how manufacturers may introduce into U.S. 
commerce partially complete engines that have an exemption or a 
certificate of conformity held by a secondary engine manufacturer and 
are not yet in a certified configuration. See the standard-setting part 
to determine whether and how the provisions of this section apply. 
(Note: See Sec.  1068.261 for provisions related to manufacturers 
introducing into U.S. commerce partially complete engines for which they 
hold the certificate of conformity.) This exemption is temporary as 
described in paragraph (g) of this section.
    (a) The provisions of this section generally apply where the 
secondary engine manufacturer has substantial control over the design 
and assembly of emission controls. In unusual circumstances we may allow 
other secondary engine manufacturers to use these provisions. In 
determining whether a manufacturer has substantial control over the 
design and assembly of emission controls, we would consider the degree 
to which the secondary engine manufacturer would be able to ensure that 
the engine will conform to the regulations in its final configuration. 
Such secondary engine manufacturers may finish assembly of partially 
complete engines in the following cases:
    (1) You obtain an engine that is not fully assembled with the intent 
to manufacture a complete engine.
    (2) You obtain an engine with the intent to modify it before it 
reaches the ultimate purchaser.
    (3) You obtain an engine with the intent to install it in equipment 
that will be subject to equipment-based standards.
    (b) Manufacturers may introduce into U.S. commerce partially 
complete engines as described in this section if they have a written 
request for such engines from a secondary engine manufacturer that has 
certified the engine and will finish the engine assembly. The written 
request must include a statement that the secondary engine manufacturer 
has a certificate of conformity for the engine and identify a valid 
engine family name associated with each engine model ordered (or the 
basis for an exemption if applicable, as specified in paragraph (e) of 
this section). The original engine manufacturer must apply a removable 
label meeting the requirements of Sec.  1068.45 that identifies the 
corporate name of the original manufacturer and states that the engine 
is exempt under the provisions of Sec.  1068.262. The name of the 
certifying manufacturer must also be on the label or, alternatively, on 
the bill of lading that accompanies the engines during shipment. The 
original engine manufacturer may not apply a permanent emission control 
information label identifying the engine's eventual status as a 
certified engine.
    (c) If you are the secondary engine manufacturer and you will hold 
the certificate, you must include the following information in your 
application for certification:
    (1) Identify the original engine manufacturer of the partially 
complete engine or of the complete engine you will modify.
    (2) Describe briefly how and where final assembly will be completed. 
Specify how you have the ability to ensure that the engines will conform 
to

[[Page 484]]

the regulations in their final configuration. (Note: Paragraph (a) of 
this section prohibits using the provisions of this section unless you 
have substantial control over the design and assembly of emission 
controls.)
    (3) State unconditionally that you will not distribute the engines 
without conforming to all applicable regulations.
    (d) If you are a secondary engine manufacturer and you are already a 
certificate holder for other families, you may receive shipment of 
partially complete engines after you apply for a certificate of 
conformity but before the certificate's effective date. In this case, 
all the provisions of Sec.  1068.103(c)(1) through (3) apply. This 
exemption allows the original manufacturer to ship engines after you 
have applied for a certificate of conformity. Manufacturers may 
introduce into U.S. commerce partially complete engines as described in 
this paragraph (d) if they have a written request for such engines from 
a secondary engine manufacturer stating that the application for 
certification has been submitted (instead of the information we specify 
in paragraph (b) of this section). We may set additional conditions 
under this paragraph (d) to prevent circumvention of regulatory 
requirements. Consistent with Sec.  1068.103(c), we may also revoke an 
exemption under this paragraph (d) if we have reason to believe that the 
application for certification will not be approved or that the engines 
will otherwise not reach a certified configuration before reaching the 
ultimate purchaser. This may require that you export the engines.
    (e) The provisions of this section also apply for shipping partially 
complete engines if the engine is covered by a valid exemption and there 
is no valid engine family name that could be used to represent the 
engine model. Unless we approve otherwise in advance, you may do this 
only when shipping engines to secondary engine manufacturers that are 
certificate holders. In this case, the secondary engine manufacturer 
must identify the regulatory cite identifying the applicable exemption 
instead of a valid engine family name when ordering engines from the 
original engine manufacturer.
    (f) If secondary engine manufacturers determine after receiving an 
engine under this section that the engine will not be covered by a 
certificate or exemption as planned, they may ask us to allow for 
shipment of the engines back to the original engine manufacturer or to 
another secondary engine manufacturer. This might occur in the case of 
an incorrect shipment or excess inventory. We may modify the provisions 
of this section as appropriate to address these cases.
    (g) Both original and secondary engine manufacturers must keep the 
records described in this section for at least five years, including the 
written request for engines and the bill of lading for each shipment (if 
applicable). The written request is deemed to be a submission to EPA and 
is thus subject to the reporting requirements of Sec.  1068.101(a)(2).
    (h) These provisions are intended only to allow secondary engine 
manufacturers to obtain or transport engines in the specific 
circumstances identified in this section so any exemption under this 
section expires when the engine reaches the point of final assembly 
identified in paragraph (c)(2) of this section.
    (i) For purposes of this section, an allowance to introduce 
partially complete engines into U.S. commerce includes a conditional 
allowance to sell, introduce, or deliver such engines into commerce in 
the United States or import them into the United States. It does not 
include a general allowance to offer such partially complete engines for 
sale because this exemption is intended to apply only for cases in which 
the certificate holder already has an arrangement to purchase the 
engines from the original engine manufacturer. This exemption does not 
allow the original engine manufacturer to subsequently offer the engines 
for sale to a different manufacturer who will hold the certificate 
unless that second manufacturer has also complied with the requirements 
of this part. The exemption does not apply for any individual engines 
that are not labeled as specified in this section or which are shipped 
to someone who is not a certificate holder.

[[Page 485]]

    (j) We may suspend, revoke, or void an exemption under this section, 
as follows:
    (1) We may suspend or revoke your exemption if you fail to meet the 
requirements of this section. We may suspend or revoke an exemption 
related to a specific secondary engine manufacturer if that manufacturer 
sells engines that are in not in a certified configuration in violation 
of the regulations. We may disallow this exemption for future shipments 
to the affected secondary engine manufacturer or set additional 
conditions to ensure that engines will be assembled in the certified 
configuration.
    (2) We may void an exemption for all the affected engines if you 
intentionally submit false or incomplete information or fail to keep and 
provide to EPA the records required by this section.
    (3) The exemption is void for an engine that is shipped to a company 
that is not a certificate holder or for an engine that is shipped to a 
secondary engine manufacturer that is not in compliance with the 
requirements of this section.
    (4) The secondary engine manufacturer may be liable for causing a 
prohibited act if voiding the exemption is due to its own actions.
    (k) No exemption is needed to import equipment that does not include 
an engine. No exemption from exhaust emission standards is available 
under this section for equipment subject to equipment-based standards if 
the engine has been installed.

[81 FR 74229, Oct. 25, 2016]



Sec.  1068.265  Provisions for engines/equipment conditionally 
exempted from certification.

    In some cases, exempted engines may need to meet alternate emission 
standards as a condition of the exemption. For example, replacement 
engines exempted under Sec.  1068.240 in many cases need to meet the 
same standards as the engines they are replacing. The standard-setting 
part may similarly exempt engines/equipment from all certification 
requirements, or allow us to exempt engines/equipment from all 
certification requirements for certain cases, but require the engines/
equipment to meet alternate standards. In these cases, all the following 
provisions apply:
    (a) Your engines/equipment must meet the alternate standards we 
specify in (or pursuant to) the exemption section, and all other 
requirements applicable to engines/equipment that are subject to such 
standards.
    (b) You need not apply for and receive a certificate for the exempt 
engines/equipment. However, you must comply with all the requirements 
and obligations that would apply to the engines/equipment if you had 
received a certificate of conformity for them unless we specifically 
waive certain requirements.
    (c) You must have emission data from test engines/equipment using 
the appropriate procedures that demonstrate compliance with the 
alternate standards unless the engines/equipment are identical in all 
material respects to engines/equipment that you have previously 
certified to standards that are the same as, or more stringent than, the 
alternate standards. Note that ``engines/equipment that you have 
previously certified'' does not include any engines/equipment initially 
covered by a certificate that was later voided or otherwise invalidated, 
or engines/equipment that we have determined did not fully conform to 
the regulations.
    (d) See the provisions of the applicable exemption for labeling 
instructions, including those related to the compliance statement and 
other modifications to the label otherwise required in the standard-
setting part. If we do not identify specific labeling requirements for 
an exempted engine, you must meet the labeling requirements in the 
standard-setting part, with the following exceptions:
    (1) Modify the family designation by eliminating the character that 
identifies the model year.
    (2) We may also specify alternative language to replace the 
compliance statement otherwise required in the standard-setting part.
    (e) You may not generate emission credits for averaging, banking, or 
trading with engines/equipment meeting requirements under the provisions 
of this section.

[[Page 486]]

    (f) Keep records to show that you meet the alternate standards as 
follows:
    (1) If your exempted engines/equipment are identical to previously 
certified engines/equipment, keep your most recent application for 
certification for the certified family.
    (2) If you previously certified a similar family, but have modified 
the exempted engines/equipment in a way that changes them from their 
previously certified configuration, keep your most recent application 
for certification for the certified family, a description of the 
relevant changes, and any test data or engineering evaluations that 
support your conclusions.
    (3) If you have not previously certified a similar family, keep all 
the records we specify for the application for certification and any 
additional records the standard-setting part requires you to keep.
    (g) We may require you to send us an annual report of the engines/
equipment you produce under this section.



                            Subpart D_Imports



Sec.  1068.301  General provisions for importing engines/equipment.

    (a) This subpart applies to you if you import into the United States 
engines or equipment subject to EPA emission standards or equipment 
containing engines subject to EPA emission standards.
    (b) In general, engines/equipment that you import must be covered by 
a certificate of conformity unless they were built before emission 
standards started to apply. This subpart describes the limited cases 
where we allow importation of exempt or excluded engines/equipment. If 
an engine has an exemption from exhaust emission standards, you may 
import the equipment under the same exemption. Imported engines/
equipment that are exempt or excluded must have a label as described in 
the specific exemption or exclusion. If the regulation does not include 
specific labeling requirements, apply a label meeting the requirements 
of Sec.  1068.45 that identifies your corporate name and describes the 
basis for the exemption or exclusion.
    (c) U.S. Customs and Border Protection may prevent you from 
importing engines or equipment if you do not meet the requirements of 
this subpart. In addition, U.S. Customs and Border Protection 
regulations may contain other requirements for engines/equipment 
imported into the United States (see 19 CFR Chapter I).
    (d) Complete the appropriate EPA declaration before importing any 
engines or equipment. These forms may be submitted and stored 
electronically and are available on the Internet at http://www.epa.gov/
OTAQ/imports/ or by phone at 734-214-4100. Importers must keep these 
records for five years and make them available promptly upon request.
    (e) The standard-setting part may define uncertified engines/
equipment to be ``new'' upon importation, whether or not they have 
already been placed into service. This may affect how the provisions of 
this subpart apply for your engines/equipment. (See the definition of 
``new'' and other relevant terms in the standard-setting part.)

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74231, Oct. 25, 2016; 88 
FR 4716, Jan. 24, 2023]



Sec.  1068.305  How do I get an exemption or exclusion for imported
engines/equipment?

    (a) You must meet the requirements of the specific exemption or 
exclusion you intend to use, including any labeling requirements that 
apply, and complete the appropriate declaration form described in Sec.  
1068.301(d).
    (b) If we ask for it, prepare a written request in which you do the 
following:
    (1) Give your name, address, and telephone number.
    (2) Give the engine/equipment owner's name, address, and telephone 
number.
    (3) Identify the make, model, identification number, and original 
production year of all engines/equipment.
    (4) Identify which exemption or exclusion in this subpart allows you 
to import nonconforming engines/equipment and describe how your engine/
equipment qualifies.
    (5) Tell us where you will keep your engines/equipment if you might 
need to store them until we approve your request.

[[Page 487]]

    (6) Authorize us to inspect or test your engines/equipment as the 
Clean Air Act allows.
    (c) We may ask for more information.
    (d) You may import the nonconforming engines/equipment you identify 
in your request if you get prior written approval from us. U.S. Customs 
and Border Protection may require you to present the approval letter. We 
may temporarily or permanently approve the exemptions or exclusions, as 
described in this subpart.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74231, Oct. 25, 2016]



Sec.  1068.310  Exclusions for imported engines/equipment.

    If you show us that your engines/equipment qualify under one of the 
paragraphs of this section, we will approve your request to import such 
excluded engines/equipment. You must have our approval before importing 
engines/equipment under paragraph (a) of this section. You may, but are 
not required, to request our approval to import the engines/equipment 
under paragraph (b) through (d) of this section. Qualifying engines/
equipment are excluded as follows:
    (a) Nonroad engines/equipment used solely for competition. Nonroad 
engines/equipment that you demonstrate will be used solely for 
competition are excluded from the restrictions on imports in Sec.  
1068.301(b), but only if they are properly labeled. See the standard-
setting part for provisions related to this demonstration that may 
apply. Section 1068.101(b)(4) prohibits anyone from using these excluded 
engines/equipment for purposes other than competition. We may waive the 
labeling requirement or allow a removable label for engines/equipment 
that are being temporarily imported for one or more specific competition 
events.
    (b) Stationary engines. The definition of nonroad engine in Sec.  
1068.30 does not include certain engines used in stationary 
applications. Such engines (and equipment containing such engines) may 
be subject to the standards of 40 CFR part 60. Engines that are excluded 
from the definition of nonroad engine in this part and are not required 
to be certified to standards under 40 CFR part 60 are not subject to the 
restrictions on imports in Sec.  1068.301(b), but only if they are 
properly labeled and there is clear and convincing evidence that each 
engine will be used in a stationary application (see paragraph (2)(iii) 
of the definition of ``Nonroad engine''). Section 1068.101 restricts the 
use of stationary engines for non-stationary purposes unless they are 
certified under 40 CFR part 60 to the same standards that would apply to 
nonroad engines for the same model year.
    (c) Hobby engines. The standard-setting parts exclude engines used 
in reduced-scale models of vehicles that are not capable of transporting 
a person.
    (d) Other engines/equipment. The standard-setting parts may exclude 
engines/equipment used in certain applications. For example, engines 
used in aircraft are generally excluded. Engines/equipment used in 
underground mining are excluded if they are regulated by the Mine Safety 
and Health Administration.
    (e) Labeling. For engines/equipment imported under paragraph (a) or 
(b) of this section, you must add a permanent label, consistent with 
Sec.  1068.45, with at least the following items unless the standard-
setting part includes other specific labeling requirements or we approve 
alternate label language that is more accurate for your engine/
equipment:
    (1) Include the heading ``EMISSION CONTROL INFORMATION''.
    (2) Include your full corporate name and trademark.
    (3) State the engine displacement (in liters or cubic centimeters). 
We may also require that you include maximum engine power. If the 
engine's power is not established, state the approximate power.
    (4) State: ``THIS ENGINE IS EXEMPT FROM THE REQUIREMENTS OF 
[identify the part referenced in Sec.  1068.1(a) that would otherwise 
apply], AS PROVIDED IN [identify the paragraph authorizing the exemption 
(for example, ``40 CFR 1068.310(a)'')]. INSTALLING THIS ENGINE IN ANY 
DIFFERENT APPLICATION MAY BE A VIOLATION OF FEDERAL LAW SUBJECT TO CIVIL 
PENALTY.''

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74231, Oct. 25, 2016; 87 
FR 4717, Jan. 24, 2023]

[[Page 488]]



Sec.  1068.315  Permanent exemptions for imported engines/equipment.

    We may approve a permanent exemption from the restrictions on 
imports under Sec.  1068.301(b) under the following conditions:
    (a) National security exemption. You may import an engine or piece 
of equipment under the national security exemption in Sec.  1068.225.
    (b) Manufacturer-owned engine/equipment exemption. You may import 
manufacturer-owned engines/equipment, as described in Sec.  1068.215.
    (c) Replacement engine exemption. You may import a nonconforming 
replacement engine as described in Sec.  1068.240. To use this 
exemption, you must be a certificate holder for a family we regulate 
under the same part as the replacement engine.
    (d) Extraordinary circumstances exemption. You may import a 
nonconforming engine or piece of equipment if we grant hardship relief 
as described in Sec.  1068.245.
    (e) Small-volume manufacturer exemption. You may import a 
nonconforming engine or piece of equipment if we grant hardship relief 
for a small-volume manufacturer, as described in Sec.  1068.250.
    (f) Equipment-manufacturer hardship exemption. You may import a 
nonconforming engine if we grant an exemption for the transition to new 
or revised emission standards, as described in Sec.  1068.255.
    (g) [Reserved]
    (h) Identical configuration exemption. Unless specified otherwise in 
the standard-setting part, you may import nonconforming engines/
equipment if they are identical in all material respects to certified 
engines/equipment produced by the same manufacturer, subject to the 
following provisions:
    (1) You must meet all the following criteria:
    (i) You have owned the engines/equipment for at least six months.
    (ii) You agree not to sell, lease, donate, trade, or otherwise 
transfer ownership of the engines/equipment for at least five years. The 
only acceptable way to dispose of the engines/equipment during this 
five-year period is to destroy or export them.
    (iii) You use data or evidence sufficient to show that the engines/
equipment are in a configuration that is identical in all material 
respects to engines/equipment the original manufacturer has certified to 
meet emission standards that apply at the time the manufacturer finished 
assembling or modifying the engines/equipment in question. If you modify 
the engines/equipment to make them identical, you must completely follow 
the original manufacturer's written instructions.
    (2) We will tell you in writing if we find the information 
insufficient to show that the engines/equipment are eligible for the 
identical configuration exemption. We will then not consider your 
request further until you address our concerns.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74231, Oct. 25, 2016; 88 
FR 4717, Jan. 24, 2023]



Sec.  1068.325  Temporary exemptions for imported engines/equipment.

    You may import engines/equipment under certain temporary exemptions, 
subject to the conditions in this section. We may ask U.S. Customs and 
Border Protection to require a specific bond amount to make sure you 
comply with the requirements of this subpart. You may not sell or lease 
one of these exempted engines/equipment while it is in the United States 
except as specified in this section or Sec.  1068.201(i). You must 
eventually export the engine/equipment as we describe in this section 
unless it conforms to a certificate of conformity or it qualifies for 
one of the permanent exemptions in Sec.  1068.315 or the standard-
setting part.
    (a) Exemption for repairs or alterations. You may temporarily import 
nonconforming engines/equipment solely for repair or alteration, subject 
to our advance approval as described in paragraph (j) of this section. 
You may operate the engine/equipment in the United States only as 
necessary to repair it, alter it, or ship it to or from the service 
location. Export the engine/equipment directly after servicing is 
complete, or confirm that it has been destroyed.

[[Page 489]]

    (b) Testing exemption. You may temporarily import nonconforming 
engines/equipment for testing if you follow the requirements of Sec.  
1068.210, subject to our advance approval as described in paragraph (j) 
of this section. You may operate the engines/equipment in the United 
States only as needed to perform tests. The testing exemption expires 
one year after you import the engine/equipment unless we approve an 
extension. The engine/equipment must be exported before the exemption 
expires. You may sell or lease the engines/equipment consistent with the 
provisions of Sec.  1068.210.
    (c) Display exemption. You may temporarily import nonconforming 
engines/equipment for display if you follow the requirements of Sec.  
1068.220, subject to our advance approval as described in paragraph (j) 
of this section. The display exemption expires one year after you import 
the engine/equipment, unless we approve your request for an extension. 
The engine/equipment must be exported (or destroyed) by the time the 
exemption expires or directly after the display concludes, whichever 
comes first.
    (d) Export exemption. You may temporarily import nonconforming 
engines/equipment to export them, as described in Sec.  1068.230. Label 
the engine/equipment as described in Sec.  1068.230. You may sell or 
lease the engines/equipment for operation outside the United States 
consistent with the provisions of Sec.  1068.230.
    (e) Diplomatic or military exemption. You may temporarily import 
nonconforming engines/equipment if you represent a foreign government in 
a diplomatic or military capacity. U.S Customs and Border Protection may 
require that you show your written confirmation from the U.S. State 
Department that you qualify for the diplomatic or military exemption or 
a copy of your orders for military duty in the United States. We will 
rely on the State Department or your military orders to determine when 
your diplomatic or military status expires, at which time you must 
export your exempt engines/equipment.
    (f) Delegated-assembly exemption. You may import a nonconforming 
engine for final assembly under the provisions of Sec.  1068.261. You 
may sell or lease the engines/equipment consistent with the provisions 
of Sec.  1068.261.
    (g) Exemption for partially complete engines. The following 
provisions apply for importing partially complete engines and used 
engines that become new as a result of importation:
    (1) You may import a partially complete engine by shipping it from 
one of your facilities to another under the provisions of Sec.  
1068.260(c) if you also apply a removable label meeting the requirements 
of Sec.  1068.45 that identifies your corporate name and states that the 
engine is exempt under the provisions of Sec.  1068.325(g).
    (2) You may import an engine if another company already has a 
certificate of conformity and will be modifying the engine to be in its 
final certified configuration or a final exempt configuration if you 
meet the labeling and other requirements of Sec.  1068.262. If you are 
importing a used engine that becomes new as a result of importation, you 
must meet all the requirements that apply to original engine 
manufacturers under Sec.  1068.262. You may sell or lease the engines 
consistent with the provisions of Sec.  1068.262.
    (h)-(i) [Reserved]
    (j) Approvals. For the exemptions in this section requiring our 
approval, you must send a request to the Designated Compliance Officer 
before importing the engines/equipment. We will approve your request if 
you meet all the applicable requirements and conditions. If another 
section separately requires that you request approval for the exemption, 
you may combine the information requirements in a single request. 
Include the following information in your request:
    (1) Identify the importer of the engine/equipment and the applicable 
postal address, e-mail address, and telephone number.
    (2) Identify the engine/equipment owner and the applicable postal 
address, e-mail address, and telephone number.
    (3) Identify the engine/equipment by model number (or name), serial 
number, and original production year.
    (4) Identify the specific regulatory provision under which you are 
seeking an exemption.

[[Page 490]]

    (5) Acknowledge that EPA enforcement officers may conduct inspect 
88ions or testing as allowed under the Clean Air Act.
    (6) Include any additional information we specify for demonstrating 
that you qualify for the exemption.

[76 FR 57489, Sept. 15, 2011; 81 FR 74231, Oct. 25, 2016; 88 FR 4717, 
Jan. 24, 2023]



Sec.  1068.335  Penalties for violations.

    (a) All imported engines/equipment. Unless you comply with the 
provisions of this subpart, importation of nonconforming engines/
equipment violates sections 203 and 213(d) of the Clean Air Act (42 
U.S.C. 7522 and 7547(d)). You may then have to export the engines/
equipment, pay civil penalties, or both. U.S. Customs and Border 
Protection may seize unlawfully imported engines and equipment.
    (b) Temporarily imported engines/equipment. If you do not comply 
with the provisions of this subpart for a temporary exemption under 
Sec.  1068.325, you may forfeit the total amount of the bond in addition 
to the sanctions we identify in paragraph (a) of this section. We will 
consider an engine or piece of equipment to be exported if it has been 
destroyed or delivered to U.S. Customs and Border Protection for export 
or other disposition under applicable Customs laws and regulations. EPA 
or U.S. Customs and Border Protection may offer you a grace period to 
allow you to export temporarily exempted engines/equipment without 
penalty after the exemption expires.



Sec.  1068.360  Restrictions for assigning a model year to imported
engines and equipment.

    This section includes limitations on assigning a model year to 
engines and equipment that are imported in a year later than the model 
year in which they were manufactured, except as specified in paragraph 
(e) of this section.
    (a) The term ``model year'' is defined in each of the standard-
setting parts. These definitions may vary slightly to address the 
different categories of engines and equipment. Except as specified in 
paragraphs (b) and (c) of this section, the emission standards and other 
emission-related requirements that apply for an imported engine or piece 
of equipment are determined by the model year as defined in the 
applicable standard-setting part and the provisions of 40 CFR 
1068.105(a).
    (b) This paragraph (b) applies for the importation of engines and 
equipment that have not been placed into service, where the importation 
occurs in any calendar year that is more than one year after the named 
model year of the engine or equipment when emission control requirements 
applying to current engines are different than for engines or equipment 
in the named model year, unless they are imported under special 
provisions for Independent Commercial Importers as allowed under the 
standard-setting part. Regardless of what other provisions of this 
subchapter U specify for the model year of the engine or equipment, such 
engines and equipment are deemed to have an applicable model year no 
more than one year earlier than the calendar year in which they are 
imported. For example, a new engine identified as a 2007 model-year 
product that is imported on January 31, 2010 will be treated as a 2009 
model-year engine; the same engine will be treated as a 2010 model-year 
engine if it is imported any time in calendar year 2011.
    (c) If you claim that an engine or piece of equipment is not subject 
to standards--or is subject to standards less stringent than those 
currently in place--based on its original manufacture date because it 
has already been placed into service, you must provide clear and 
convincing evidence that it has already been placed into service. Such 
evidence must generally include, but not be limited to, documentary 
evidence of purchase and maintenance history and visible wear that is 
consistent with the reported manufacture date. Importing products for 
resale or importing more than one engine or piece of equipment at a time 
would generally require a greater degree of evidence under this 
paragraph (c). If you do not satisfactorily demonstrate that the engine 
or equipment has already been placed into service, the provisions of 
paragraph (b) of this section apply.
    (d) Nothing in this section should be interpreted to allow 
circumvention of the requirements of this part by mis-

[[Page 491]]

stating or mis-labeling the model year of engines or equipment. For 
example, this section does not permit engines imported in the same year 
that they are manufactured to be treated as an engine manufactured in 
the previous year. To verify compliance with the provisions of this 
section, we may require you to verify the original manufacture date of 
the engine or equipment based on manufacturing records, title-transfer 
documents, service records, or other documentation.
    (e) If all the current emission control requirements are the same as 
in the named model year, the provisions of this section do not apply.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74232, Oct. 25, 2016]



                Subpart E_Selective Enforcement Auditing



Sec.  1068.401  What is a selective enforcement audit?

    (a) We may conduct or require you as a certificate holder to conduct 
emission tests on production engines/equipment in a selective 
enforcement audit. This requirement is independent of any requirement 
for you to routinely test production-line engines/equipment. Where there 
are multiple entities meeting the definition of manufacturer, we may 
require manufacturers other than the certificate holder to conduct or 
participate in the audit as necessary. For products subject to 
equipment-based standards, but tested using engine-based test 
procedures, this subpart applies to the engines and/or the equipment, as 
applicable. Otherwise this subpart applies to engines for products 
subject to engine-based standards and to equipment for products subject 
to equipment-based standards.
    (b) If we send you a signed test order, you must follow its 
directions and the provisions of this subpart. We may tell you where to 
test the engines/equipment. This may be where you produce the engines/
equipment or any other emission testing facility. You are responsible 
for all testing costs whether the testing is conducted at your facility 
or another facility.
    (c) If we select one or more of your families for a selective 
enforcement audit, we will send the test order to the person who signed 
the application for certification or we will deliver it in person.
    (d) If we do not select a testing facility, notify the Designated 
Compliance Officer within one working day of receiving the test order 
where you will test your engines/equipment.
    (e) You must do everything we require in the audit without delay. We 
may suspend or revoke your certificate of conformity for the affected 
engine families if you do not fulfill your obligations under this 
subpart.

[81 FR 74232, Oct. 25, 2016]



Sec.  1068.405  What is in a test order?

    (a) In the test order, we will specify the following things:
    (1) The family we have identified for testing. We may also specify 
individual configurations.
    (2) The engine/equipment assembly plant, storage facility, or (if 
you import the engines/equipment) port facility from which you must 
select engines/equipment.
    (3) The procedure for selecting engines/equipment for testing, 
including a selection rate.
    (4) The test procedures, duty cycles, and test points, as 
appropriate, for testing the engines/equipment to show that they meet 
emission standards.
    (b) We may state that we will select the test engines/equipment.
    (c) We may identify alternate families or configurations for testing 
in case we determine the intended engines/equipment are not available 
for testing or if you do not produce enough engines/equipment to meet 
the minimum rate for selecting test engines/equipment.
    (d) We may include other directions or information in the test 
order.
    (e) We may ask you to show us that you meet any additional 
requirements that apply to your engines/equipment (closed crankcases, 
for example).
    (f) In anticipation of a potential audit, you may give us a list of 
your preferred families and the corresponding assembly plants, storage 
facilities, or (if you import the engines/equipment) port facilities 
from which we should select engines/equipment for testing. The 
information would apply only for a single model year so it would

[[Page 492]]

be best to include this information in your application for 
certification. If you give us this list before we issue a test order, we 
will consider your recommendations, but we may select different engines/
equipment.
    (g) If you also do routine production-line testing with the selected 
family in the same time period, the test order will tell you what 
changes you might need to make in your production-line testing schedule.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74132, Oct. 25, 2016]



Sec.  1068.410  How must I select and prepare my engines/equipment?

    (a) Selecting engines/equipment. Select engines/equipment as 
described in the test order. If you are unable to select test engines/
equipment this way, you may ask us to approve an alternate plan as long 
as you make the request before you start selecting engines/equipment.
    (b) Assembling engines/equipment. Produce and assemble test engines/
equipment using your normal production and assembly process for that 
family.
    (1) Notify us directly if you make any change in your production, 
assembly, or quality control processes that might affect emissions 
between the time you receive the test order and the time you finish 
selecting test engines/equipment.
    (2) If you do not fully assemble engines/equipment at the specified 
location, we will describe in the test order how to select components to 
finish assembling the engines/equipment. Assemble these components onto 
the test engines/equipment using your documented assembly and quality 
control procedures.
    (c) Modifying engines/equipment. Once an engine or piece of 
equipment is selected for testing, you may adjust, repair, prepare, or 
modify it or check its emissions only if one of the following is true:
    (1) You document the need for doing so in your procedures for 
assembling and inspecting all your production engines/equipment and make 
the action routine for all the engines/equipment in the family.
    (2) This subpart otherwise allows your action.
    (3) We approve your action in advance.
    (d) Engine/equipment malfunction. If an engine/equipment malfunction 
prevents further emission testing, ask us to approve your decision to 
either repair the engine or delete it from the test sequence.
    (e) Setting adjustable parameters. Before any test, we may adjust or 
require you to adjust any adjustable parameter to any setting within its 
physically adjustable range.
    (1) [Reserved]
    (2) We may make or specify adjustments within the physically 
adjustable range by considering their effect on emission levels. We may 
also consider how likely it is that someone will make such an adjustment 
with in-use engines/equipment.
    (f) Stabilizing emission levels. (1) Before you test production-line 
engines/equipment for exhaust emission, you may operate the engine/
equipment to stabilize the exhaust emission levels. Using good 
engineering judgment, operate your engines/equipment in a way that 
represents the way production engines/equipment will be used. You may 
operate each engine or piece of equipment for no more than the greater 
of two periods:
    (i) 50 hours.
    (ii) The number of hours you operated your emission-data engine/
equipment for certifying the family (see 40 CFR part 1065, subpart E).
    (2) Use good engineering judgment and follow the standard-setting 
part to stabilize equipment for evaporative emissions, where 
appropriate.
    (g) Damage during shipment. If shipping the engine/equipment to a 
remote facility for testing under a selective enforcement audit makes 
necessary an adjustment or repair, you must wait until after the initial 
emission test to do this work. We may waive this requirement if the test 
would be impossible or unsafe or if it would permanently damage the 
engine/equipment. Report to us, in your written report under Sec.  
1068.450, all adjustments or repairs you make on test engines/equipment 
before each test.

[[Page 493]]

    (h) Shipping engines/equipment. If you need to ship engines/
equipment to another facility for testing, make sure the test engines/
equipment arrive at the test facility within 24 hours after being 
selected. You may ask that we allow more time if you are unable to do 
this.
    (i) Retesting after invalid tests. You may retest an engine or piece 
of equipment if you determine an emission test is invalid under the 
standard-setting part. Explain in your written report reasons for 
invalidating any test and the emission results from all tests. If you 
retest an engine or piece of equipment and, within ten days after 
testing, ask to substitute results of the new tests for the original 
ones, we will answer within ten days after we receive your information.
    (j) Retesting after reaching a fail decision. You may retest your 
engines/equipment once a fail decision for the audit has been reached 
based on the first test on each engine or piece of equipment under Sec.  
1068.420(c). You may test each engine or piece of equipment up to a 
total of three times, but you must perform the same number of tests on 
each engine or piece of equipment. You may further operate the engine/
equipment to stabilize emission levels before testing, subject to the 
provisions of paragraph (f) of this section. We may approve retesting at 
other times if you send us a request with satisfactory justification.

[73 FR 59344, Oct. 8, 2008, as amended at 75 FR 23064, Apr. 30, 2010]



Sec.  1068.415  How do I test my engines/equipment?

    (a) Use the test procedures specified in the standard-setting part 
for showing that your engines/equipment meet emission standards. The 
test order will give further testing instructions.
    (b) If no test cells are available at a given facility, you may make 
alternate testing arrangements with our approval.
    (c) Test at least two engines/equipment in each 24-hour period 
(including void tests). However, for engines with maximum engine power 
above 560 kW, you may test one engine per 24-hour period. If you request 
and justify it, we may approve a lower testing rate.
    (d) For exhaust emissions, accumulate service on test engines/
equipment at a minimum rate of 6 hours per engine or piece of equipment 
during each 24-hour period; however, service accumulation to stabilize 
an engine's emission levels may not take longer than eight days. The 
first 24-hour period for service accumulation begins when you finish 
preparing an engine or piece of equipment for testing. The minimum 
service accumulation rate does not apply on weekends or holidays. We may 
approve a longer stabilization period or a lower service accumulation 
rate if you request and justify it. We may require you to accumulate 
hours more rapidly than the minimum rate, as appropriate. Plan your 
service accumulation to allow testing at the rate specified in paragraph 
(c) of this section. Select operation for accumulating operating hours 
on your test engines/equipment to represent normal in-use operation for 
the family.
    (e) Test engines/equipment in the same order you select them.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74232, Oct. 25, 2016]



Sec.  1068.420  How do I know when my engine family fails an SEA?

    (a) A failed engine or piece of equipment is one whose final 
deteriorated test results exceed an applicable emission standard for any 
regulated pollutant.
    (b) Continue testing engines/equipment until you reach a pass 
decision for all pollutants or a fail decision for one pollutant, as 
described in paragraph (c) of this section.
    (c) You reach a pass decision for the SEA requirements when the 
number of failed engines/equipment is less than or equal to the pass 
decision number in Appendix A to this subpart for the total number of 
engines/equipment tested. You reach a fail decision for the SEA 
requirements when the number of failed engines/equipment is greater than 
or equal to the fail decision number in Appendix A to this subpart for 
the total number of engines/equipment you test. An acceptable quality 
level of 40 percent is the basis for the pass or fail decision.

[[Page 494]]

    (d) Consider test results in the same order as the engine/equipment 
testing sequence.
    (e) If you reach a pass decision for one pollutant, but need to 
continue testing for another pollutant, we will not use these later test 
results for the pollutant with the pass decision as part of the SEA.
    (f) Appendix A to this subpart lists multiple sampling plans. Use 
the sampling plan for the projected sales volume you reported in your 
application for the audited family.
    (g) We may choose to stop testing after any number of tests.
    (h) If we test some of your engines/equipment in addition to your 
own testing, we may decide not to include your test results as official 
data for those engines/equipment if there is substantial disagreement 
between your testing and our testing. We will reinstate your data as 
valid if you show us that we made an error and your data are correct.
    (i) If we rely on our test data instead of yours, we will notify you 
in writing of our decision and the reasons we believe your facility is 
not appropriate for doing the tests we require under this subpart. You 
may request in writing that we consider your test results from the same 
facility for future testing if you show us that you have made changes to 
resolve the problem.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74232, Oct. 25, 2016]



Sec.  1068.425  What happens if one of my production-line engines/equipment
exceeds the emission standards?

    (a) If one of your production-line engines/equipment fails to meet 
one or more emission standards (see Sec.  1068.420), the certificate of 
conformity is automatically suspended for that engine or piece of 
equipment. You must take the following actions before your certificate 
of conformity can cover that engine or piece of equipment:
    (1) Correct the problem and retest the engine/equipment to show it 
complies with all emission standards.
    (2) Include in your written report a description of the test results 
and the remedy for each engine or piece of equipment (see Sec.  
1068.450).
    (b) You may ask for a hearing relative to the suspended certificate 
of conformity for the failing engine/equipment as specified in subpart G 
of this part.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74232, Oct. 25, 2016]



Sec.  1068.430  What happens if a family fails an SEA?

    (a) We may suspend your certificate of conformity for a family if it 
fails the SEA under Sec.  1068.420. The suspension may apply to all 
facilities producing engines/equipment from a family even if you find 
noncompliant engines/equipment only at one facility.
    (b) We will tell you in writing if we suspend your certificate in 
whole or in part. We will not suspend a certificate until at least 15 
days after the family fails the SEA. The suspension is effective when 
you receive our notice.
    (c) You may ask for a hearing as described in subpart G of this part 
up to 15 days after we suspend the certificate for a family. If we agree 
that we used erroneous information in deciding to suspend the 
certificate before a hearing is held, we will reinstate the certificate.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74232, Oct. 25, 2016]



Sec.  1068.435  May I sell engines/equipment from a family with
a suspended certificate of conformity?

    You may sell engines/equipment that you produce after we suspend the 
family's certificate of conformity only if one of the following occurs:
    (a) You test each engine or piece of equipment you produce and show 
it complies with emission standards that apply.
    (b) We conditionally reinstate the certificate for the family. We 
may do so if you agree to recall all the affected engines/equipment and 
remedy any noncompliance at no expense to the owner if later testing 
shows that engines/equipment in the family still do not comply.

[[Page 495]]



Sec.  1068.440  How do I ask EPA to reinstate my suspended certificate?

    (a) Send us a written report asking us to reinstate your suspended 
certificate. In your report, identify the reason for the SEA failure, 
propose a remedy, and commit to a date for carrying it out. In your 
proposed remedy include any quality control measures you propose to keep 
the problem from happening again.
    (b) Give us test data from production engines/equipment showing that 
engines/equipment in the remedied family comply with all the emission 
standards that apply.

[73 FR 59344, Oct. 8, 2008, as amended at 75 FR 23064, Apr. 30, 2010]



Sec.  1068.445  When may EPA revoke my certificate under this subpart
and how may I sell these engines/equipment again?

    (a) We may revoke your certificate for a family in the following 
cases:
    (1) You do not meet the reporting requirements under this subpart.
    (2) Your family fails an SEA and your proposed remedy to address a 
suspended certificate is inadequate to solve the problem or requires you 
to change the engine/equipment's design or emission control system.
    (b) To sell engines/equipment from a family with a revoked 
certificate of conformity, you must modify the family and then show it 
complies with the applicable requirements.
    (1) If we determine your proposed design change may not control 
emissions for the engine/equipment's full useful life, we will tell you 
within five working days after receiving your report. In this case we 
will decide whether production-line testing will be enough for us to 
evaluate the change or whether you need to do more testing.
    (2) Unless we require more testing, you may show compliance by 
testing production-line engines/equipment as described in this subpart.
    (3) We will issue a new or updated certificate of conformity when 
you have met these requirements.



Sec.  1068.450  What records must I send to EPA?

    (a) Within 30 days of the end of each audit, send us a report with 
the following information:
    (1) Describe any facility used to test production-line engines/
equipment and state its location.
    (2) State the total U.S.-directed production volume and number of 
tests for each family.
    (3) Describe your test engines/equipment, including the family's 
identification and the engine/equipment's model year, build date, model 
number, identification number, and number of hours of operation before 
testing for each test engine or piece of equipment.
    (4) Identify where you accumulated hours of operation on the 
engines/equipment and describe the procedure and schedule you used.
    (5) Provide the test number; the date, time and duration of testing; 
test procedure; initial test results before and after rounding; final 
test results; and final deteriorated test results for all tests. Provide 
the emission figures for all measured pollutants. Include information 
for both valid and invalid tests and the reason for any invalidation.
    (6) Describe completely and justify any nonroutine adjustment, 
modification, repair, preparation, maintenance, or test for the test 
engine/equipment if you did not report it separately under this subpart. 
Include the results of any emission measurements, regardless of the 
procedure or type of equipment.
    (7) Report on each failed engine or piece of equipment as described 
in Sec.  1068.425.
    (b) We may ask you to add information to your written report, so we 
can determine whether your new engines/equipment conform to the 
requirements of this subpart.
    (c) An authorized representative of your company must sign the 
following statement: We submit this report under Sections 208 and 213 of 
the Clean Air Act. Our testing conformed completely with the 
requirements of 40 CFR part 1068. We have not changed production 
processes or quality-control procedures for the family in a way that 
might affect the emission control from production engines/equipment. All 
the information in this report is true and

[[Page 496]]

accurate to the best of my knowledge. I know of the penalties for 
violating the Clean Air Act and the regulations. (Authorized Company 
Representative)
    (d) Send reports of your testing to the Designated Compliance 
Officer using an approved information format. If you want to use a 
different format, send us a written request with justification for a 
waiver.
    (e) We may post test results on publicly accessible databases and we 
will send copies of your reports to anyone from the public who asks for 
them, consistent with Sec.  1068.11.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74232, Oct. 25, 2016; 88 
FR 4718, Jan. 24, 2023]



Sec.  1068.455  What records must I keep?

    (a) We may review your records at any time so it is important to 
keep required information readily available. Organize and maintain your 
records as described in this section.
    (b) Keep paper records for testing under this subpart for one full 
year after you complete all the testing required for the selective 
enforcement audit. For additional storage, you may use any format or 
media.
    (c) Keep a copy of the written reports described in Sec.  1068.450.
    (d) Keep the following additional records:
    (1) The names of supervisors involved in each test.
    (2) The name of anyone who authorizes adjusting, repairing, 
preparing, or modifying a test engine/equipment and the names of all 
supervisors who oversee this work.
    (3) If you shipped the engine/equipment for testing, the date you 
shipped it, the associated storage or port facility, and the date the 
engine/equipment arrived at the testing facility.
    (4) Any records related to your audit that are not in the written 
report.
    (5) A brief description of any significant events during testing not 
otherwise described in the written report or in this section.
    (e) If we ask, you must give us projected or actual production for a 
family. Include each assembly plant if you produce engines/equipment at 
more than one plant.
    (f) We may ask you to keep or send other information necessary to 
implement this subpart.



     Sec. Appendix A to Subpart E of Part 1068--Plans for Selective 
                          Enforcement Auditing

    The following tables describe sampling plans for selective 
enforcement audits, as described in Sec.  1068.420:


                                      Table A-1--Sampling Plan Code Letter
----------------------------------------------------------------------------------------------------------------
                                                         Minimum number of tests
   Projected family       Code letter \1\    ----------------------------------------------   Maximum number of
        sales                                        To pass                To fail                 tests
----------------------------------------------------------------------------------------------------------------
            20-50                     AA                      3                      5                     20
            20-99                      A                      4                      6                     30
          100-299                      B                      5                      6                     40
          300-499                       C                     5                      6                     50
            500 +                      D                      5                      6                     60
----------------------------------------------------------------------------------------------------------------
\1\ A manufacturer may optionally use either the sampling plan for code letter ``AA'' or sampling plan for code
  letter ``A'' for Selective Enforcement Audits of families with annual sales between 20 and 50 engines/
  equipment. Additionally, the manufacturer may switch between these plans during the audit.


                       Table A-2--Sampling Plans for Different Engine Family Sales Volumes
----------------------------------------------------------------------------------------------------------------
                      AA                     A                     B                    C                D
           -----------------------------------------------------------------------------------------------------
 Stage \a\                                                                                                  Fail
              Pass       Fail      Pass      Fail      Pass      Fail      Pass     Fail    Pass     
----------------------------------------------------------------------------------------------------------------
        1   ..........  .........  .........  .........  .........  .........  .........  .......  .......
        2   ..........  .........  .........  .........  .........  .........  .........  .......  .......
        3           0   .........  .........  .........  .........  .........  .........  .......  .......
        4           0   .........         0   .........  .........  .........  .........  .......  .......
        5           1          5          0   .........         0   .........         0   .......       0
        6           1          6          1          6          1          6          0        6        0    6
        7           2          6          1          7          1          7          1        7        1    7
        8           2          7          2          7          2          7          2        7        2    8
        9           3          7          2          8          2          8          2        8        2    8

[[Page 497]]

 
       10           3          8          3          8          3          8          3        9        3    9
       11           4          8          3          8          3          9          3        9        3    9
       12           4          9          4          9          4          9          4       10        4   10
       13           5          9          5         10          4         10          4       10        4   10
       14           5         10          5         10          5         10          5       11        5   11
       15           6         10          6         11          5         11          5       11        5   11
       16           6         10          6         11          6         12          6       12        6   12
       17           7         10          7         12          6         12          6       12        6   12
       18           8         10          7         12          7         13          7       13        7   13
       19           8         10          8         13          8         13          7       13        7   13
       20           9         10          8         13          8         14          8       14        8   14
       21   ..........  .........         9         14          9         14          8       14        8   14
       22   ..........  .........        10         14          9         15          9       15        9   15
       23   ..........  .........        10         15         10         15         10       15        9   15
       24   ..........  .........        11         15         10         16         10       16       10   16
       25   ..........  .........        11         16         11         16         11       16       11   16
       26   ..........  .........        12         16         11         17         11       17       11   17
       27   ..........  .........        12         17         12         17         12       17       12   17
       28   ..........  .........        13         17         12         18         12       18       12   18
       29   ..........  .........        14         17         13         18         13       18       13   19
       30   ..........  .........        16         17         13         19         13       19       13   19
       31   ..........  .........  .........  .........        14         19         14       19       14   20
       32   ..........  .........  .........  .........        14         20         14       20       14   20
       33   ..........  .........  .........  .........        15         20         15       20       15   21
       34   ..........  .........  .........  .........        16         21         15       21       15   21
       35   ..........  .........  .........  .........        16         21         16       21       16   22
       36   ..........  .........  .........  .........        17         22         16       22       16   22
       37   ..........  .........  .........  .........        17         22         17       22       17   23
       38   ..........  .........  .........  .........        18         22         18       23       17   23
       39   ..........  .........  .........  .........        18         22         18       23       18   24
       40   ..........  .........  .........  .........        21         22         19       24       18   24
       41   ..........  .........  .........  .........  .........  .........        19       24       19   25
       42   ..........  .........  .........  .........  .........  .........        20       25       19   26
       43   ..........  .........  .........  .........  .........  .........        20       25       20   26
       44   ..........  .........  .........  .........  .........  .........        21       26       21   27
       45   ..........  .........  .........  .........  .........  .........        21       27       21   27
       46   ..........  .........  .........  .........  .........  .........        22       27       22   28
       47   ..........  .........  .........  .........  .........  .........        22       27       22   28
       48   ..........  .........  .........  .........  .........  .........        23       27       23   29
       49   ..........  .........  .........  .........  .........  .........        23       27       23   29
       50   ..........  .........  .........  .........  .........  .........        26       27       24   30
       51   ..........  .........  .........  .........  .........  .........  .........  .......      24   30
       52   ..........  .........  .........  .........  .........  .........  .........  .......      25   31
       53   ..........  .........  .........  .........  .........  .........  .........  .......      25   31
       54   ..........  .........  .........  .........  .........  .........  .........  .......      26   32
       55   ..........  .........  .........  .........  .........  .........  .........  .......      26   32
       56   ..........  .........  .........  .........  .........  .........  .........  .......      27   33
       57   ..........  .........  .........  .........  .........  .........  .........  .......      27   33
       58   ..........  .........  .........  .........  .........  .........  .........  .......      28   33
       59   ..........  .........  .........  .........  .........  .........  .........  .......      28   33
       60   ..........  .........  .........  .........  .........  .........  .........  .......      32   33
----------------------------------------------------------------------------------------------------------------
\a\ Stage refers to the cumulative number of engines/equipment tested.



       Subpart F_Reporting Defects and Recalling Engines/Equipment



Sec.  1068.501  How do I report emission-related defects?

    This section addresses the certificate holder's responsibility to 
investigate and report emission-related defects in design, materials, or 
workmanship. The provisions of this section do not limit your liability 
under this part or the Clean Air Act. For example, selling an engine/
equipment that does not conform to your application for certification is 
a violation of Sec.  1068.101(a)(1) independent of the requirements of 
this section. The requirements of this section apply separately to each 
certificate holder if there is more than one certificate holder for the 
equipment.

[[Page 498]]

    (a) General provisions. As a certifying manufacturer, you must 
investigate in certain circumstances whether engines/equipment that have 
been introduced into U.S. commerce under your certificate have 
incorrect, improperly installed, or otherwise defective emission-related 
components or systems. This includes defects in design, materials, or 
workmanship. You must also send us reports as specified by this section.
    (1) This section addresses defects for any of the following 
emission-related components or systems containing the following 
components:
    (i) Electronic control units, aftertreatment devices, fuel-metering 
components, EGR-system components, crankcase-ventilation valves, all 
components related to charge-air compression and cooling, and all 
sensors associated with any of these components.
    (ii) For engines and equipment subject to evaporative emission 
standards, fuel tanks, fuel caps, and fuel lines and connectors.
    (iii) Any other component whose primary purpose is to reduce 
emissions.
    (iv) Any other component whose failure would commonly increase 
emissions of any regulated pollutant without significantly degrading 
engine/equipment performance.
    (2) The requirements of this section relate to defects in any of the 
components or systems identified in paragraph (a)(1) of this section if 
the defects might affect any of the parameters or specifications in 
Appendix II of this part or might otherwise affect the emissions of any 
regulated pollutant.
    (3) For the purposes of this section, defects do not include damage 
to emission-related components or systems (or maladjustment of 
parameters) caused by owners improperly maintaining or abusing their 
engines/equipment.
    (4) The requirements of this section do not apply to emission 
control information labels. Note however, that Sec.  1068.101(a)(1) 
prohibits the sale of engines/equipment without proper labels, which 
also applies to misprinted labels.
    (5) You must track the information specified in paragraph (b)(1) of 
this section. You must assess this data at least every three months to 
evaluate whether you exceed the thresholds specified in paragraphs (e) 
and (f) of this section. Where thresholds are based on a percentage of 
engines/equipment in the family, use actual U.S.-directed production 
volumes for the whole model year when they become available. Use 
projected production figures until the actual production figures become 
available. You are not required to collect additional information other 
than that specified in paragraph (b)(1) of this section before reaching 
a threshold for an investigation specified in paragraph (e) of this 
section.
    (6) You may ask us to allow you to use alternate methods for 
tracking, investigating, reporting, and correcting emission-related 
defects. In your request, explain and demonstrate why you believe your 
alternate system will be at least as effective in the aggregate in 
tracking, identifying, investigating, evaluating, reporting, and 
correcting potential and actual emissions-related defects as the 
requirements in this section. In this case, provide all available data 
necessary to demonstrate why an alternate system is appropriate for your 
engines/equipment and how it will result in a system at least as 
effective as that required under this section.
    (7) If we determine that emission-related defects result in a 
substantial number of properly maintained and used engines/equipment not 
conforming to the regulations of this chapter during their useful life, 
we may order you to conduct a recall of your engines/equipment (see 
Sec.  1068.505).
    (8) Send all reports required by this section to the Designated 
Compliance Officer.
    (9) This section distinguishes between defects and possible defects. 
A possible defect exists anytime there is an indication that an 
emission-related component or system might have a defect, as described 
in paragraph (b)(1) of this section.
    (b) Investigation of possible defects. Investigate possible defects 
as follows:
    (1) If the number of engines/equipment that have a possible defect, 
as defined by this paragraph (b)(1), exceeds a threshold specified in 
paragraph (e) of this section, you must conduct an investigation to 
determine if an emission-related component or system is actually 
defective. You must classify

[[Page 499]]

an engine/equipment component or system as having a possible defect if 
any of the following sources of information shows there is a significant 
possibility that a defect exists:
    (i) A warranty claim is submitted for the component, whether this is 
under your emission-related warranty or any other warranty.
    (ii) Your quality-assurance procedures suggest that a defect may 
exist.
    (iii) You receive any other information for which good engineering 
judgment would indicate the component or system may be defective, such 
as information from dealers, field-service personnel, equipment 
manufacturers, hotline complaints, in-use testing, or engine diagnostic 
systems.
    (2) If the number of shipped replacement parts for any individual 
component is high enough that good engineering judgment would indicate a 
significant possibility that a defect exists, you must conduct an 
investigation to determine if it is actually defective. Note that this 
paragraph (b)(2) does not require data-tracking or recording provisions 
related to shipment of replacement parts.
    (3) Your investigation must be prompt, thorough, consider all 
relevant information, follow accepted scientific and engineering 
principles, and be designed to obtain all the information specified in 
paragraph (d) of this section.
    (4) Your investigation needs to consider possible defects that occur 
only within the useful life period, or within five years after the end 
of the model year, whichever is longer.
    (5) You must continue your investigation until you are able to show 
that there is no emission-related defect or you obtain all the 
information specified for a defect report in paragraph (d) of this 
section.
    (6) If a component with a possible defect is used in additional 
families or model years, you must investigate whether the component may 
be defective when used in these additional families or model years, and 
include these results in any defect report you send under paragraph (c) 
of this section.
    (7) If your initial investigation concludes that the number of 
engines/equipment with a defect is fewer than any of the thresholds 
specified in paragraph (f) of this section, but other information later 
becomes available that may show that the number of engines/equipment 
with a defect exceeds a threshold, then you must resume your 
investigation. If you resume an investigation, you must include the 
information from the earlier investigation to determine whether to send 
a defect report.
    (c) Reporting defects. You must send us a defect report in either of 
the following cases:
    (1) Your investigation shows that the number of engines/equipment 
with a defect exceeds a threshold specified in paragraph (f) of this 
section. Send the defect report within 21 days after the date you 
identify this number of defective engines/equipment. See paragraph (h) 
of this section for reporting requirements that apply if the number of 
engines/equipment with a defect does not exceed any of the thresholds in 
paragraph (f) of this section.
    (2) You know there are emission-related defects for a component or 
system in a number of engines/equipment that exceeds a threshold 
specified in paragraph (f) of this section, regardless of how you obtain 
this information. Send the defect report within 21 days after you learn 
that the number of defects exceeds a threshold. Send us an updated 
defect report anytime you have significant additional information.
    (d) Contents of a defect report. Include the following information 
in a defect report:
    (1) Your corporate name and a person to contact regarding this 
defect.
    (2) A description of the defect, including a summary of any 
engineering analyses and associated data, if available.
    (3) A description of the engines/equipment that have the defect, 
including families, models, and range of production dates.
    (4) An estimate of the number and percentage of each class or 
category of affected engines/equipment that have the defect, and an 
explanation of how you determined this number. Describe any statistical 
methods you used under paragraph (g)(6) of this section.

[[Page 500]]

    (5) An estimate of the defect's impact on emissions, with an 
explanation of how you calculated this estimate and a summary of any 
emission data demonstrating the impact of the defect, if available.
    (6) A description of your plan for addressing the defect or an 
explanation of your reasons for not believing the defects must be 
addressed.
    (e) Thresholds for conducting a defect investigation. You must begin 
a defect investigation based on the following number of engines/
equipment that may have the defect:
    (1) For engines/equipment with maximum engine power at or below 560 
kW:
    (i) For families with annual production below 500 units: 50 or more 
engines/equipment.
    (ii) For families with annual production from 500 to 50,000 units: 
more than 10.0 percent of the total number of engines/equipment in the 
family.
    (iii) For families with annual production from 50,000 to 550,000 
units: more than the total number of engines/equipment represented by 
the following equation:

Investigation threshold = 5,000 + (Production units--50,000) x 0.04

    (iv) For families with annual production above 550,000 units: 25,000 
or more engines/equipment.
    (2) For engines/equipment with maximum engine power greater than 560 
kW:
    (i) For families with annual production below 250 units: 25 or more 
engines/equipment.
    (ii) For families with annual production at or above 250 units: more 
than 10.0 percent of the total number of engines/equipment in the 
family.
    (f) Thresholds for filing a defect report. You must send a defect 
report based on the following number of engines/equipment that have the 
defect:
    (1) For engines/equipment with maximum engine power at or below 560 
kW:
    (i) For families with annual production below 1,000 units: 20 or 
more engines/equipment.
    (ii) For families with annual production from 1,000 to 50,000 units: 
more than 2.0 percent of the total number of engines/equipment in the 
family.
    (iii) For families with annual production from 50,000 to 550,000 
units: more than the total number of engines/equipment represented by 
the following equation:

Reporting threshold = 1,000 + (Production units--50,000) x 0.01

    (iv) For families with annual production above 550,000 units: 6,000 
or more engines/equipment.
    (2) For engines/equipment with maximum engine power greater than 560 
kW:
    (i) For families with annual production below 150 units: 10 or more 
engines/equipment.
    (ii) For families with annual production from 150 to 750 units: 15 
or more engines/equipment.
    (iii) For families with annual production above 750 units: more than 
2.0 percent of the total number of engines/equipment in the family.
    (g) How to count defects. (1) Track defects separately for each 
model year and family as much as possible. If information is not 
identifiable by model year or family, use good engineering judgment to 
evaluate whether you exceed a threshold in paragraph (e) or
    (f) of this section. Consider only your U.S.-directed production 
volume.
    (2) Within a family, track defects together for all components or 
systems that are the same in all material respects. If multiple 
companies separately supply a particular component or system, treat each 
company's component or system as unique.
    (3) For engine-based standards, if a possible defect is not 
attributed to any specific part of the engine, consider the complete 
engine a distinct component for evaluating whether you exceed a 
threshold in paragraph (e) of this section. For equipment-based 
standards, if a possible defect is not attributed to any specific part 
of the equipment, consider the complete piece of equipment a distinct 
component for evaluating whether you exceed a threshold in paragraph (e) 
of this section.
    (4) If you correct defects before they reach the ultimate purchaser 
as a result of your quality-assurance procedures, count these against 
the investigation thresholds in paragraph (e) of this section unless you 
routinely check every engine or piece of equipment in the family. Do not 
count any corrected

[[Page 501]]

defects as actual defects under paragraph (f) of this section.
    (5) Use aggregated data from all the different sources identified in 
paragraph (b)(1) of this section to determine whether you exceed a 
threshold in paragraphs (e) and (f) of this section.
    (6) If information is readily available to conclude that the 
possible defects identified in paragraph (b)(1) of this section are 
actual defects, count these toward the reporting thresholds in paragraph 
(f) of this section.
    (7) During an investigation, use appropriate statistical methods to 
project defect rates for engines/equipment that you are not otherwise 
able to evaluate. For example, if 75 percent of the components replaced 
under warranty are available for evaluation, it would be appropriate to 
extrapolate known information on failure rates to the components that 
are unavailable for evaluation. Take steps as necessary to prevent bias 
in sampled data. Make adjusted calculations to take into account any 
bias that may remain.
    (h) Investigation reports. Once you trigger an investigation 
threshold under paragraph (e) of this section, you must report your 
progress and conclusions. In your reports, include the information 
specified in paragraph (d) of this section, or explain why the 
information is not relevant. Send us the following reports:
    (1) While you are investigating, send us mid-year and end-of-year 
reports to describe the methods you are using and the status of the 
investigation. Send these status reports no later than June 30 and 
December 31 of each year.
    (2) If you find that the number of components or systems with an 
emission-related defect exceeds a threshold specified in paragraph (f) 
of this section, send us a report describing your findings within 21 
days after the date you reach this conclusion.
    (3) If you find that the number of components or systems with an 
emission-related defect does not exceed any of the thresholds specified 
in paragraph (f) of this section, send us a final report supporting this 
conclusion. For example, you may exclude warranty claims that resulted 
from misdiagnosis and you may exclude defects caused by improper 
maintenance, improper use, or misfueling. Send this report within 21 
days after the date you reach this conclusion.
    (i) Future production. If you identify a design or manufacturing 
defect that prevents engines/equipment from meeting the requirements of 
this part, you must correct the defect as soon as possible for future 
production of engines/equipment in every family affected by the defect. 
This applies without regard to whether you are required to conduct a 
defect investigation or submit a defect report under this section.

[73 FR 59344, Oct. 8, 2008, as amended at 75 FR 23064, Apr. 30, 2010; 81 
FR 74232, Oct. 25, 2016]



Sec.  1068.505  How does the recall program work?

    (a) If we make a determination that a substantial number of properly 
maintained and used engines/equipment within a given class or category 
do not conform to the regulations of this chapter during their useful 
life, you must submit a plan to remedy the nonconformity of your 
engines/equipment. We will notify you of our determination in writing. 
Our notice will identify the class or category of engines/equipment 
affected and describe how we reached our conclusion. If this happens, 
you must meet the requirements and follow the instructions in this 
subpart. You must remedy at your expense all engines/equipment that 
experienced the nonconformity during the useful life in spite of being 
properly maintained and used, as described in Sec.  1068.510(a)(7), 
regardless of their age or extent of service accumulation at the time of 
repair. You may not transfer this expense to a dealer (or equipment 
manufacturer for engine-based standards) through a franchise or other 
agreement.
    (b) You may ask for a hearing if you disagree with our determination 
(see subpart G of this part).
    (c) Unless we withdraw the determination of noncompliance, you must 
respond to it by sending a remedial plan to the Designated Compliance 
Officer. We will designate a date by which you must send us the remedial 
plan; the designated date will be no sooner than 45 days after we notify 
you, and no sooner than 30 days after a hearing.

[[Page 502]]

    (d) Once you have sold engines/equipment to the ultimate purchaser, 
we may inspect or test the engines/equipment only if the purchaser 
permits it, or if state or local inspection programs separately provide 
for it.
    (e) You may ask us to allow you to conduct your recall differently 
than specified in this subpart, consistent with section 207(c) of the 
Clean Air Act (42 U.S.C. 7541(c)).
    (f) You may do a voluntary recall under Sec.  1068.535 unless we 
have made the determination described in Sec.  1068.535(a).
    (g) For purposes of recall, ``owner'' means someone who owns an 
engine or piece of equipment affected by a remedial plan.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74233, Oct. 25, 2016]



Sec.  1068.510  How do I prepare and apply my remedial plan?

    (a) In your remedial plan, describe all of the following:
    (1) The class or category of engines/equipment to be recalled, 
including the number of engines/equipment involved and the model year or 
other information needed to identify the engines/equipment.
    (2) The modifications, alterations, repairs, corrections, 
adjustments, or other changes you will make to correct the affected 
engines/equipment.
    (3) A brief description of the studies, tests, and data that support 
the effectiveness of the remedy you propose to use.
    (4) The instructions you will send to those who will repair the 
engines/equipment under the remedial plan.
    (5) How you will determine the owners' names and addresses.
    (6) How you will notify owners; include a copy of any notification 
letters.
    (7) The proper maintenance or use you will specify, if any, as a 
condition to be eligible for repair under the remedial plan. Describe 
how these specifications meet the provisions of paragraph (e) of this 
section. Describe how the owners should show they meet your conditions.
    (8) The steps owners must take for you to do the repair. You may set 
a date or a range of dates, specify the amount of time you need, and 
designate certain facilities to do the repairs.
    (9) Which company (or group) you will assign to do or manage the 
repairs.
    (10) If your employees or authorized warranty agents will not be 
doing the work, state who will and describe their qualifications.
    (11) How you will ensure an adequate and timely supply of parts.
    (12) The effect of proposed changes on fuel consumption, 
driveability, and safety of the engines/equipment you will recall; 
include a brief summary of the information supporting these conclusions.
    (13) How you intend to label the engines/equipment you repair and 
where you will place the label on the engine/equipment (see Sec.  
1068.515).
    (b) We may require you to add information if it is needed to 
evaluate your remedial plan.
    (c) We may require you to test the proposed repair to show it will 
remedy the noncompliance.
    (d) Use all reasonable means to locate owners. We may require you to 
use government or commercial registration lists to get owners' names and 
addresses so your notice will be effective.
    (e) The maintenance or use that you specify as a condition for 
eligibility under the remedial plan may include only things you can show 
would cause noncompliance. Do not require use of a component or service 
identified by brand, trade, or corporate name unless we approved this 
approach with your original certificate of conformity. Also, do not 
place conditions on who maintained the engine/equipment.
    (f) We may require you to adjust your repair plan if we determine 
owners would be without their engines or equipment for an unreasonably 
long time.
    (g) We will tell you in writing within 15 days of receiving your 
remedial plan whether we have approved or disapproved it. We will 
explain our reasons for any disapproval.
    (h) Begin notifying owners within 15 days after we approve your 
remedial plan. If we hold a hearing, but do not change our position 
about the noncompliance, you must begin notifying

[[Page 503]]

owners within 60 days after we complete the hearing unless we specify a 
later deadline.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74233, Oct. 25, 2016]



Sec.  1068.515  How do I mark or label repaired engines/equipment?

    (a) Attach a label to engines/equipment you repair under the 
remedial plan. At your discretion, you may label or mark engines/
equipment you inspect but do not repair. Designate the specific recall 
campaign on the label.
    (b) Make the label from a durable material suitable for its planned 
location. Make sure no one can remove the label without destroying or 
defacing it.
    (c) Identify the facility where you repaired or inspected the 
engine/equipment on the label, or keep records of this information for 
each vehicle and give it to us if we ask for it.
    (d) We may waive or modify the labeling requirements if we determine 
they are overly burdensome.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74233, Oct. 25, 2016]



Sec.  1068.520  How do I notify affected owners?

    (a) Notify owners by first class mail or e-mail unless we say 
otherwise. We may require you to use certified mail. Include the 
following in your notice:
    (1) State: ``The U.S. Environmental Protection Agency has determined 
that your engine/equipment may be emitting pollutants in excess of the 
federal emission standards as defined in Title 40 of the Code of Federal 
Regulations. These emission standards were established to protect the 
public health or welfare from air pollution.''
    (2) State that you (or someone you designate) will repair these 
engines/equipment at your expense.
    (3) If we approved maintenance and use conditions in your remedial 
plan, state that you will make these repairs only if owners show their 
engines/equipment meet the conditions for proper maintenance and use. 
Describe these conditions and how owners should prove their engines/
equipment are eligible for repair.
    (4) Describe the components your repair will affect and say 
generally how you will repair the engines/equipment.
    (5) State that the engine/equipment, if not repaired, may fail an 
emission inspection test if state or local law requires one.
    (6) Describe any adverse effects on its performance or driveability 
that would be caused by not repairing the engine/equipment.
    (7) Describe any adverse effects on the functions of other 
components that would be caused by not repairing the engine/equipment.
    (8) Specify the date you will start the repairs, the amount of time 
you will need to do them, and where you will do them. Include any other 
information owners may need to know.
    (9) Allow for the owner to inform you using one of the following 
methods if they have sold the engine/equipment:
    (i) Send a self-addressed card that owners can mail back to you; 
include a space for owners to write the name and address of a buyer.
    (ii) Provide owners with a toll-free number and an e-mail address or 
Web site they can use to identify the name and address of a buyer.
    (10) State that owners should call you at a phone number you give to 
report any difficulty in obtaining repairs.
    (11) State: ``To ensure your full protection under the emission 
warranty on your [engine/equipment] by federal law, and your right to 
participate in future recalls, we recommend you have your [engine/
equipment] serviced as soon as possible. We may consider your not 
servicing it to be improper maintenance.''
    (b) We may require you to add information to your notice or to send 
more notices if we determine this is reasonable and necessary to ensure 
an effective recall.
    (c) You may not in any communication with owners or dealers say or 
imply that your noncompliance does not exist or that it will not degrade 
air quality.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74233, Oct. 25, 2016]



Sec.  1068.525  What records must I send to EPA?

    (a) Send us a copy of all communications related to the remedial 
plan you

[[Page 504]]

sent to dealers and others doing the repairs. Mail or e-mail us the 
information at the same time you send it to others.
    (b) From the time you begin to notify owners, send us a report 
within 25 days of the end of each calendar quarter. Send reports for six 
consecutive quarters or until all the engines/equipment are inspected, 
whichever comes first. In these reports, identify the following:
    (1) The range of dates you needed to notify owners.
    (2) The total number of notices sent.
    (3) The number of engines/equipment you estimate fall under the 
remedial plan (explain how you determined this number).
    (4) The cumulative number of engines/equipment you inspected under 
the remedial plan.
    (5) The cumulative number of these engines/equipment you found 
needed the specified repair.
    (6) The cumulative number of these engines/equipment you have 
repaired.
    (7) The cumulative number of engines/equipment you determined to be 
unavailable due to exportation, theft, retirement, or other reasons 
(specify).
    (8) The cumulative number of engines/equipment you disqualified for 
not being properly maintained or used.
    (c) If your estimated number of engines/equipment falling under the 
remedial plan changes, change the estimate in your next report and add 
an explanation for the change.
    (d) We may ask for more information.
    (e) We may waive reporting requirements or adjust the reporting 
schedule.
    (f) If anyone asks to see the information in your reports, we will 
follow the provisions of Sec.  1068.10 for handling confidential 
information.



Sec.  1068.530  What records must I keep?

    We may review your records at any time so it is important that you 
keep required information readily available. Keep records associated 
with your recall campaign for five years after you send the last report 
we require under Sec.  1068.525(b). Organize and maintain your records 
as described in this section.
    (a) Keep a paper copy of the written reports described in Sec.  
1068.525.
    (b) Keep a record of the names and addresses of owners you notified. 
For each engine or piece of equipment, state whether you did any of the 
following:
    (1) Inspected the engine/equipment.
    (2) Disqualified the engine/equipment for not being properly 
maintained or used.
    (3) Completed the prescribed repairs.
    (c) You may keep the records in paragraph (b) of this section in any 
form we can inspect, including computer databases.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74233, Oct. 25, 2016]



Sec.  1068.535  How can I do a voluntary recall for emission-related problems?

    If we have made a determination that a substantial number of 
properly maintained and used engines/equipment do not conform to the 
regulations of this chapter during their useful life, you may not use a 
voluntary recall or other alternate means to meet your obligation to 
remedy the noncompliance. Thus, this section applies only if you learn 
that your family does not meet the requirements of this chapter and we 
have not made such a determination.
    (a) To do a voluntary recall under this section, first send the 
Designated Compliance Officer a plan, following the guidelines in Sec.  
1068.510. Within 15 days, we will send you our comments on your plan.
    (b) Once we approve your plan, start notifying owners and carrying 
out the specified repairs. Make reasonable efforts to carry out the 
recall as quickly as possible.
    (c) From the time you start the recall campaign, send us a report 
within 25 days of the end of each calendar quarter, following the 
guidelines in Sec.  1068.525(b). Send reports for six consecutive 
quarters or until all the engines/equipment are inspected, whichever 
comes first.
    (d) Keep your reports and the supporting information as described in 
Sec.  1068.530.

[[Page 505]]



                           Subpart G_Hearings

    Source: 81 FR 74233, Oct. 25, 2016, unless otherwise noted.



Sec.  1068.601  Overview.

    The regulations of this chapter involve numerous provisions that may 
result in EPA making a decision or judgment that you may consider 
adverse to your interests. For example, our decisions might require you 
to pay penalties, or you might consider that our decisions will limit 
your business activities or put you at a competitive disadvantage. As 
specified in the regulations in this chapter, this might involve an 
opportunity for an informal hearing or a formal hearing that follows 
specific procedures and is directed by a Presiding Officer. The 
regulations in this chapter generally specify when we would hold a 
hearing. In limited circumstances, we may grant a request for a hearing 
related to adverse decisions regarding regulatory provisions for which 
we do not specifically describe the possibility of asking for a hearing.
    (a) If you request a hearing regarding our decision to assess 
administrative penalties under Sec.  1068.125, we will hold a formal 
hearing according to the provisions of 40 CFR 22.1 through 22.32 and 
22.34.
    (b) For other issues where the regulation allows for a hearing in 
response to an adverse decision, you may request an informal hearing as 
described in Sec.  1068.650. Sections 1068.610 through 1068.630 describe 
when and how to request an informal hearing under various circumstances.
    (c) The time limits we specify are calendar days and include 
weekends and holidays, except that a deadline falling on a Saturday, 
Sunday, or a federal holiday is understood to move to the next business 
day. Your filing will be considered timely based on the following 
criteria relative to the specified deadline:
    (1) The postmarked date for items sent by U.S. mail must be on or 
before the specified date.
    (2) The ship date for items sent from any location within the United 
States by commercial carriers must be on or before the specified date.
    (3) Items sent by mail or courier from outside the United States 
must be received by the specified date.
    (4) The time and date stamp on an email message must be at or before 
5:00 p.m. on the specified date (in either the source or destination 
time zone).
    (5) The time and date stamp on faxed pages must be at or before 5:00 
p.m. on the specified date (in either the source or destination time 
zone).
    (6) Hand-delivered items must be received by the appropriate 
personnel by 3:00 p.m. on the specified date.
    (d) See the standard-setting part for additional information. If the 
standard-setting part specifies any provisions that are contrary to 
those described in this subpart, the provisions of the standard-setting 
part apply instead of those described in this subpart.

[81 FR 74233, Oct. 25, 2016, as amended at 88 FR 4718, Jan. 24, 2023]



Sec.  1068.610  Request for hearing--suspending, revoking, or voiding a certificate of conformity.

    (a) You may request an informal hearing as described in Sec.  
1068.650 if you disagree with our decision to suspend, revoke, or void a 
certificate of conformity.
    (b) If you request a hearing regarding the outcome of a testing 
regimen with established evaluation criteria, such as selective 
enforcement audits or routine production-line testing, we will hold a 
hearing limited to the following issues that are relevant to your 
circumstances:
    (1) Whether tests were conducted in accordance with applicable 
regulations.
    (2) Whether test equipment was properly calibrated and functioning.
    (3) Whether specified sampling procedures were followed to select 
engines/equipment for testing.
    (4) Whether there is a basis for determining that the problems 
identified do not apply for engines/equipment produced at plants other 
than the one from which engines/equipment were selected for testing.
    (c) You must send your hearing request in writing to the Designated 
Compliance Officer no later than 30 days after we notify you of our 
decision

[[Page 506]]

to suspend, revoke, or void your certificate, or by some later deadline 
we specify. If the deadline passes, we may nevertheless grant you a 
hearing at our discretion.
    (d) Your hearing request must include the following information:
    (1) Identify the classes or categories of engines/equipment that 
will be the subject of the hearing.
    (2) State briefly which issues you will raise at the hearing for 
each affected class or category of engines/equipment.
    (3) Specify why you believe the hearing will conclude in your favor 
for each of the issues you will raise.
    (4) Summarize the evidence supporting your position on each of the 
issues you will raise and include any supporting data.
    (e) We will approve your request for an informal hearing if we find 
that your request raises a substantial factual issue in the decision we 
made that, if addressed differently, could alter the outcome of that 
decision.



Sec.  1068.615  Request for hearing--denied application for certification,
automatically suspended certificate, and determinations related
to certification.

    (a) You may request an informal hearing as described in Sec.  
1068.650 if we deny your application for a certificate of conformity, if 
your certificate of conformity is automatically suspended under the 
regulations, or if you disagree with determinations we make as part of 
the certification process. For example, you might disagree with our 
determinations regarding adjustable parameters under Sec.  1068.50 or 
regarding your good engineering judgment under Sec.  1068.5.
    (b) You must send your hearing request in writing to the Designated 
Compliance Officer no later than 30 days after we notify you of our 
decision, or by some later deadline we specify. If the specified 
deadline passes, we may nevertheless grant you a hearing at our 
discretion.
    (c) Your hearing request must include the information specified in 
Sec.  1068.610(d).
    (d) We will approve your request for an informal hearing if we find 
that your request raises a substantial factual issue in the decision we 
made that, if addressed differently, could alter the outcome of that 
decision.



Sec.  1068.620  Request for hearing--recall.

    (a) You may request an informal hearing as described in Sec.  
1068.650 if you disagree with our decision to order a recall.
    (b) You must send your hearing request in writing to the Designated 
Compliance Officer no later than 45 days after we notify you of our 
decision, or by some later deadline we specify. If the specified 
deadline passes, we may nevertheless grant you a hearing at our 
discretion.
    (c) Your hearing request must include the information specified in 
Sec.  1068.610(d).
    (d) We will approve your request for an informal hearing if we find 
that your request raises a substantial factual issue in the decision we 
made that, if addressed differently, could alter the outcome of that 
decision.



Sec.  1068.625  Request for hearing--nonconformance penalties.

    (a) You may request an informal hearing as described in Sec.  
1068.650 if you disagree with our determination of compliance level or 
penalty calculation or both. The hearing will address only whether the 
compliance level or penalty was determined in accordance with the 
regulations.
    (b) Send a request for a hearing in writing to the Designated 
Compliance Officer within the following time frame, as applicable:
    (1) No later than 15 days after we notify you that we have approved 
a nonconformance penalty under this subpart if the compliance level is 
in the allowable range of nonconformity.
    (2) No later than 15 days after completion of the Production 
Compliance Audit if the compliance level exceeds the upper limit.
    (3) No later than 15 days after we notify you of an adverse decision 
for all other cases.
    (c) If you miss the specified deadline in paragraph (b) of this 
section, we may nevertheless grant youa hearing at our discretion.
    (d) Your hearing request must include the information specified in 
Sec.  1068.610(d).

[[Page 507]]

    (e) We will approve your request for an informal hearing if we find 
that your request raises a substantial factual issue in the decision we 
made that, if addressed differently, could alter the outcome of that 
decision.



Sec.  1068.630  Request for hearing--allowable maintenance.

    (a) Any manufacturer may request an informal hearing as described in 
Sec.  1068.650 in response to our decision to identify allowable 
maintenance associated with new technology as part of the certification 
process.
    (b) You must send your hearing request in writing to the Designated 
Compliance Officer no later than 30 days after we publish our decision 
in the Federal Register. If the deadline passes, we may nevertheless 
grant you a hearing at our discretion.
    (c) Your hearing request must include the information specified in 
Sec.  1068.610(d).
    (d) We will approve your request for an informal hearing if we find 
that your request raises a substantial factual issue in the decision we 
made that, if addressed differently, could alter the outcome of that 
decision.

[88 FR 4718, Jan. 24, 2023]



Sec.  1068.650  Procedures for informal hearings.

    (a) The following provisions apply for arranging the hearing:
    (1) After granting your request for an informal hearing, we will 
designate a Presiding Officer for the hearing.
    (2) The Presiding Officer will select the time and place for the 
hearing. The hearing must be held as soon as practicable for all parties 
involved.
    (3) The Presiding Officer may require that all argument and 
presentation of evidence be concluded by a certain date after 
commencement of the hearing.
    (b) The Presiding Officer will establish a paper or electronic 
hearing record, which may be made available for inspection. The hearing 
record includes, but is not limited to, the following materials:
    (1) All documents relating to the application for certification, 
including the certificate of conformity itself, if applicable.
    (2) Your request for a hearing and the accompanying supporting data.
    (3) Correspondence and other data relevant to the hearing.
    (4) The Presiding Officer's written decision regarding the subject 
of the hearing, together with any accompanying material.
    (c) You may appear in person or you may be represented by counsel or 
by any other representative you designate.
    (d) The Presiding Officer may arrange for a prehearing conference, 
either in response to a request from any party or at his or her own 
discretion. The Presiding Officer will select the time and place for the 
prehearing conference. The Presiding Officer will summarize the results 
of the conference and include the written summary as part of the record. 
The prehearing conference may involve consideration of the following 
items:
    (1) Simplification of the issues.
    (2) Stipulations, admissions of fact, and the introduction of 
documents.
    (3) Limitation of the number of expert witnesses.
    (4) Possibility of reaching an agreement to resolve any or all of 
the issues in dispute.
    (5) Any other matters that may aid in expeditiously and successfully 
concluding the hearing.
    (e) Hearings will be conducted as follows:
    (1) The Presiding Officer will conduct informal hearings in an 
orderly and expeditious manner. The parties may offer oral or written 
evidence; however, the Presiding Officer may exclude evidence that is 
irrelevant, immaterial, or repetitious.
    (2) Witnesses will not be required to testify under oath; however, 
the Presiding Officer must make clear that 18 U.S.C. 1001 specifies 
civil and criminal penalties for knowingly making false statements or 
representations or using false documents in any matter within the 
jurisdiction of EPA or any other department or agency of the United 
States.
    (3) Any witness may be examined or cross-examined by the Presiding 
Officer, by you, or by any other parties.

[[Page 508]]

    (4) Written transcripts must be made for all hearings. Anyone may 
purchase copies of transcripts from the reporter.
    (f) The Presiding Officer will make a final decision with written 
findings, conclusions and supporting rationale on all the substantial 
factual issues presented in the record. The findings, conclusions, and 
written decision must be provided to the parties and made a part of the 
record.



        Sec. Appendix A to Part 1068--Emission-Related Components

    This appendix specifies emission-related components that we refer to 
for describing such things as emission-related warranty or maintenance 
or requirements related to rebuilding engines. Note that inclusion of a 
component in Section III of this Appendix does not make it an emission-
related component for engines/equipment that are not subject to 
evaporative emission standards.
    I. For exhaust emissions, emission-related components include any 
engine parts related to the following systems:
    1. Air-induction system.
    2. Fuel system.
    3. Ignition system.
    4. Exhaust gas recirculation systems.
    II. The following parts are also considered emission-related 
components for exhaust emissions:
    1. Aftertreatment devices.
    2. Crankcase ventilation valves.
    3. Sensors.
    4. Electronic control units.
    III. The following parts are considered emission-related components 
for evaporative emissions:
    1. Fuel Tank.
    2. Fuel Cap.
    3. Fuel Line.
    4. Fuel Line Fittings.
    5. Clamps*.
    6. Pressure Relief Valves*.
    7. Control Valves*.
    8. Control Solenoids*.
    9. Electronic Controls*.
    10. Vacuum Control Diaphragms*.
    11. Control Cables*.
    12. Control Linkages*.
    13. Purge Valves.
    14. Vapor Hoses.
    15. Liquid/Vapor Separator.
    16. Carbon Canister.
    17. Canister Mounting Brackets.
    18. Carburetor Purge Port Connector.
    *As related to the evaporative emission control system.
    IV. Any other part or system that meets the definition of critical 
emission-related component.

[73 FR 59344, Oct. 8, 2008, as amended at 81 FR 74235, Oct. 25, 2016. 
Redesignated and amended at 88 FR 4718, Jan. 24, 2023]



     Sec. Appendix B to Part 1068--Emission-Related Parameters and 
                             Specifications

    This appendix specifies emission-related parameters and 
specifications that we refer to for describing such things as emission-
related defects or requirements related to rebuilding engines.
    I. Basic Engine Parameters for Reciprocating Engines.
    1. Compression ratio.
    2. Type of air aspiration (natural, Roots-blown, supercharged, 
turbocharged).
    3. Valves (intake and exhaust).
    a. Head diameter dimension.
    b. Valve lifter or actuator type and valve lash dimension.
    4. Camshaft timing.
    a. Valve opening--intake exhaust (degrees from top-dead center or 
bottom-dead center).
    b. Valve closing--intake exhaust (degrees from top-dead center or 
bottom-dead center).
    c. Valve overlap (degrees).
    5. Ports--two stroke engines (intake and/or exhaust).
    a. Flow area.
    b. Opening timing (degrees from top-dead center or bottom-dead 
center).
    c. Closing timing (degrees from top-dead center or bottom-dead 
center).
    II. Intake Air System.
    1. Roots blower/supercharger/turbocharger calibration.
    2. Charge air cooling.
    a. Type (air-to-air; air-to-liquid).
    b. Type of liquid cooling (engine coolant, dedicated cooling 
system).
    c. Performance.
    3. Temperature control system calibration.
    4. Maximum allowable inlet air restriction.
    III. Fuel System.
    1. General.
    a. Engine idle speed.
    b. Engine idle mixture.
    2. Carburetion.
    a. Air-fuel flow calibration.
    b. Idle mixture.
    c. Transient enrichment system calibration.
    d. Starting enrichment system calibration.
    e. Altitude compensation system calibration.
    f. Hot idle compensation system calibration.
    3. Fuel injection for spark-ignition engines.
    a. Control parameters and calibrations.
    b. Idle mixture.

[[Page 509]]

    c. Fuel shutoff system calibration.
    d. Starting enrichment system calibration.
    e. Transient enrichment system calibration.
    f. Air-fuel flow calibration.
    g. Altitude compensation system calibration.
    h. Operating pressure(s).
    i. Injector timing calibration.
    4. Fuel injection for compression-ignition engines.
    a. Control parameters and calibrations.
    b. Transient enrichment system calibration.
    c. Air-fuel flow calibration.
    d. Altitude compensation system calibration.
    e. Operating pressure(s).
    f. Injector timing calibration.
    IV. Ignition System for Spark-ignition Engines.
    1. Control parameters and calibration.
    2. Initial timing setting.
    3. Dwell setting.
    4. Altitude compensation system calibration.
    5. Spark plug voltage.
    V. Engine Cooling System--thermostat calibration.
    VI. Exhaust System--maximum allowable back pressure.
    VII. System for Controlling Exhaust Emissions.
    1. Air injection system.
    a. Control parameters and calibrations.
    b. Pump flow rate.
    2. EGR system.
    a. Control parameters and calibrations.
    b. EGR valve flow calibration.
    3. Catalytic converter system.
    a. Active surface area.
    b. Volume of catalyst.
    c. Conversion efficiency.
    4. Backpressure.
    VIII. System for Controlling Crankcase Emissions.
    1. Control parameters and calibrations.
    2. Valve calibrations.
    IX. Auxiliary Emission Control Devices (AECD).
    1. Control parameters and calibrations.
    2. Component calibration(s).
    X. System for Controlling Evaporative Emissions.
    1. Control parameters and calibrations.
    2. Fuel tank.
    a. Volume.
    b. Pressure and vacuum relief settings.
    XI. Warning Systems Related to Emission Controls.
    1. Control parameters and calibrations.
    2. Component calibrations.

[73 FR 59344, Oct. 8, 2008. Redesignated at 88 FR 4718, Jan. 24, 2023]



          Sec. Appendix C to Part 1068--High-Altitude Counties

    In some cases the standard-setting part includes requirements or 
other specifications that apply for high-altitude counties. The 
following counties have substantial populated areas above 4,000 feet 
above sea level and are therefore considered to be high-altitude 
counties:

                            STATE OF ARIZONA

Apache
Cochise
Coconino
Navajo
Yavapai

                            STATE OF COLORADO

Adams
Alamosa
Arapahoe
Archuleta
Boulder
Chaffee
Cheyenne
Clear Creek
Conejos
Costilla
Crowley
Custer
Delta
Denver
Dolores
Douglas
Eagle
Elbert
El Paso
Fremont
Garfield
Gilpin
Grand
Gunnison
Hinsdale
Huerfano
Jackson
Jefferson
Kit Carson
Lake
La Plata
Larimer
Las Animas
Lincoln
Mesa
Mineral
Moffat
Montezuma
Montrose
Morgan
Otero
Ouray
Park
Pitkin
Pueblo
Rio Blanco
Rio Grande

[[Page 510]]

Routt
Saguache
San Juan
San Miguel
Summit
Teller
Washington
Weld

                             STATE OF IDAHO

Bannock
Bear Lake
Bingham
Blaine
Bonneville
Butte
Camas
Caribou
Cassia
Clark
Custer
Franklin
Fremont
Jefferson
Lemhi
Madison
Minidoka
Oneida
Power
Teton
Valley

                            STATE OF MONTANA

Beaverhead
Deer Lodge
Gallatin
Jefferson
Judith Basin
Powell
Madison
Meagher
Park
Silver Bow
Wheatland

                            STATE OF NEBRASKA

Banner
Cheyenne
Kimball
Sioux

                             STATE OF NEVADA

Carson City
Douglas
Elko
Esmeralda
Eureka
Humboldt
Lander
Lincoln
Lyon
Mineral
Nye
Pershing
Storey
Washoe
White Pine

                           STATE OF NEW MEXICO

Bernalillo
Catron
Colfax
Curry
De Baca
Grant
Guadalupe
Harding
Hidalgo
Lincoln
Los Alamos
Luna
McKinley
Mora
Otero
Rio Arriba
Roosevelt
Sandoval
San Juan
San Miguel
Santa Fe
Sierra
Socorro
Taos
Torrance
Union
Valencia

                             STATE OF OREGON

Harney
Lake
Klamath

                             STATE OF TEXAS

Jeff Davis
Judspeth
Parmer

                              STATE OF UTAH

Beaver
Box Elder
Cache
Carbon
Daggett
Davis
Duchesne
Emery
Garfield
Grand
Iron
Juab
Kane
Millard
Morgan
Piute
Rich
Salt Lake
San Juan
Sanpete
Sevier
Summit
Tooele
Uintah

[[Page 511]]

Utah
Wasatch
Wayne
Weber

                            STATE OF WYOMING

Albany
Campbell
Carbon
Converse
Fremont
Goshen
Hot Springs
Johnson
Laramie
Lincoln
Natrona
Niobrara
Park
Platte
Sublette
Sweetwater
Teton
Uinta
Washakie
Weston

[73 FR 59344, Oct. 8, 2008. Redesignated at 88 FR 4718, Jan. 24, 2023]



PART 1074_PREEMPTION OF STATE STANDARDS AND PROCEDURES FOR 
WAIVER OF FEDERAL PREEMPTION FOR NONROAD ENGINES AND NONROAD
VEHICLES--Table of Contents



             Subpart A_Applicability and General Provisions

Sec.
1074.1 Applicability.
1074.5 Definitions.
1074.10 Scope of preemption.
1074.12 Scope of preemption--specific provisions for locomotives and 
          locomotive engines.

Appendix A to Subpart A of Part 1074--State Regulation of the Use and 
          Operation of Nonroad Internal Combustion Engines

                 Subpart B_Procedures for Authorization

1074.101 Procedures for California nonroad authorization requests.
1074.105 Criteria for granting authorization.
1074.110 Adoption of California standards by other states.
1074.115 Relationship of federal and state standards.

    Authority: 42 U.S.C. 7401-7671q.

    Source: 73 FR 59379, Oct. 8, 2008, unless otherwise noted.



             Subpart A_Applicability and General Provisions



Sec.  1074.1  Applicability.

    The requirements of this part apply with respect to state and local 
standards and other requirements relating to the control of emissions 
from nonroad engines and nonroad vehicles.



Sec.  1074.5  Definitions.

    The definitions in this section apply to this part. As used in this 
part, all undefined terms have the meaning the Act gives to them. The 
definitions follow:
    Act means the Clean Air Act, as amended, 42 U.S.C. 7401-7671q.
    Administrator means the Administrator of the Environmental 
Protection Agency and any authorized representatives.
    Commercial means an activity engaged in as a vocation.
    Construction equipment or vehicle means any internal combustion 
engine-powered machine primarily used in construction and located on 
commercial construction sites.
    Engine used in a locomotive means either an engine placed in a 
locomotive to move other equipment, freight, or passenger traffic, or an 
engine mounted on a locomotive to provide auxiliary power.
    Farm equipment or vehicle means any internal combustion engine-
powered machine primarily used in the commercial production and/or 
commercial harvesting of food, fiber, wood, or commercial organic 
products or for the processing of such products for further use on the 
farm.
    Locomotive means a piece of equipment meeting the definition of 
locomotive in 40 CFR 1033.901 that is propelled by a nonroad engine.
    New has the following meanings:
    (1) For locomotives, new has the meaning given in 40 CFR 1033.901.
    (2) For engines used in locomotives, new means an engine 
incorporated in (or intended to be incorporated in) in a new locomotive.
    (3) For other nonroad engines and equipment, new means a domestic or 
imported nonroad engine or nonroad vehicle the equitable or legal title 
to which has never been transferred to an

[[Page 512]]

ultimate purchaser. Where the equitable or legal title to an engine or 
vehicle is not transferred to an ultimate purchaser until after the 
engine or vehicle is placed into service, then the engine or vehicle 
will no longer be new once it is placed into service. A nonroad engine 
or vehicle is placed into service when it is used for its functional 
purposes. This paragraph (3) does not apply to locomotives or engines 
used in locomotives.
    Nonroad engine has the meaning given in 40 CFR 1068.30
    Primarily used means used 51 percent or more.
    States and localities means any or all of the states, commonwealths, 
and territories in the United States including the District of Columbia 
and any or all of their political subdivisions.
    Ultimate purchaser means the first person who in good faith 
purchases a new nonroad engine or new nonroad vehicle or equipment for 
purposes other than resale.
    United States has the meaning given in 40 CFR 1068.30.



Sec.  1074.10  Scope of preemption.

    (a) States and localities are preempted from adopting or enforcing 
standards or other requirements relating to the control of emissions 
from new engines smaller than 175 horsepower that are primarily used in 
farm or construction equipment or vehicles, as defined in this part. For 
equipment that is used in applications in addition to farming or 
construction activities, if the equipment is primarily used as farm and/
or construction equipment or vehicles (as defined in this part), it is 
considered farm or construction equipment or vehicles.
    (b) For nonroad engines or vehicles other than those described in 
paragraph (a) of this section and Sec.  1074.12, States and localities 
are preempted from enforcing any standards or other requirements 
relating to control of emissions from nonroad engines or vehicles except 
as provided in subpart B of this part.



Sec.  1074.12  Scope of preemption-specific provisions for 
locomotives and locomotive engines

    (a) States and localities are preempted from adopting or enforcing 
standards or other requirements relating to the control of emissions 
from new locomotives and new engines used in locomotives.
    (b) During a period equivalent in length to 133 percent of the 
useful life, expressed as MW-hrs (or miles where applicable), beginning 
at the point at which the locomotive or engine becomes new, those 
standards or other requirements which are preempted include, but are not 
limited to, the following: emission standards, mandatory fleet average 
standards, certification requirements, retrofit and aftermarket 
equipment requirements, and nonfederal in-use testing requirements. The 
standards and other requirements specified in the preceding sentence are 
preempted whether applicable to new or other locomotives or locomotive 
engines.



 Sec. Appendix A to Subpart A of Part 1074--State Regulation of the Use 
          and Operation of Nonroad Internal Combustion Engines

    (a) This appendix describes EPA's interpretation of the Clean Air 
Act regarding the authority of states to regulate the use and operation 
of nonroad engines.
    (b) EPA believes that states are not precluded under 42 U.S.C. 7543 
from regulating the use and operation of nonroad engines, such as 
regulations on hours of usage, daily mass emission limits, or sulfur 
limits on fuel; nor are permits regulating such operations precluded, 
once the engine is no longer new. EPA believes that states are precluded 
from requiring retrofitting of used nonroad engines except that states 
are permitted to adopt and enforce any such retrofitting requirements 
identical to California requirements which have been authorized by EPA 
under 42 U.S.C. 7543.

[86 FR 34590, June 29, 2021]



                 Subpart B_Procedures for Authorization



Sec.  1074.101  Procedures for California nonroad authorization requests.

    (a) California must request authorization from the Administrator to 
enforce its adopted standards and other

[[Page 513]]

requirements relating to control of emissions from nonroad engines or 
vehicles that are not preempted by Sec.  1074.10(a) or Sec.  1074.12. 
The request must include the record on which the state rulemaking was 
based.
    (b) After receiving the authorization request, the Administrator 
will provide notice and opportunity for a public hearing regarding such 
requests.



Sec.  1074.105  Criteria for granting authorization.

    (a) The Administrator will grant the authorization if California 
determines that its standards will be, in the aggregate, at least as 
protective of public health and welfare as otherwise applicable federal 
standards.
    (b) The authorization will not be granted if the Administrator finds 
that any of the following are true:
    (1) California's determination is arbitrary and capricious.
    (2) California does not need such standards to meet compelling and 
extraordinary conditions.
    (3) The California standards and accompanying enforcement procedures 
are not consistent with section 209 of the Act (42 U.S.C. 7543).
    (c) In considering any request from California to authorize the 
state to adopt or enforce standards or other requirements relating to 
control of emissions from new nonroad spark-ignition engines smaller 
than 50 horsepower, the Administrator will give appropriate 
consideration to safety factors (including the potential increased risk 
of burn or fire) associated with compliance with the California 
standard.



Sec.  1074.110  Adoption of California standards by other states.

    (a) Except as described in paragraph (b) of this section, any state 
other than California that has plan provisions approved under Part D of 
Title I of the Act (42 U.S.C. 7501 to 7515) may adopt and enforce 
emission standards for any period for nonroad engines and vehicles 
subject to the following requirements:
    (1) The state must provide notice to the Administrator that it has 
adopted such standards.
    (2) Such standards may not apply to new engines smaller than 175 
horsepower that are used in farm or construction equipment or vehicles, 
or to new locomotives or new engines used in locomotives.
    (3) Such standards and implementation and enforcement must be 
identical, for the period concerned, to the California standards 
authorized by the Administrator.
    (4) The state must adopt such standards at least two years before 
the standards first take effect.
    (5) California must have adopted such standards two years before the 
standards first take effect in the state that is adopting them under 
this section.
    (b) States and localities, other than the State of California, may 
not adopt or attempt to enforce any standard or other requirement 
applicable to the control of emissions from spark-ignition engines 
smaller than 50 horsepower, except standards or other requirements that 
were adopted by that state before September 1, 2003.



Sec.  1074.115  Relationship of federal and state standards.

    If state standards apply to a new nonroad engine or vehicle pursuant 
to authorization granted under section 209 of the Act (42 U.S.C. 7543), 
compliance with such state standards will be treated as compliance with 
the otherwise applicable standards of this chapter for engines or 
vehicles introduced into commerce in that state.

                       PARTS 1075	1089 [RESERVED]



PART 1090_REGULATION OF FUELS, FUEL ADDITIVES, 
AND REGULATED BLENDSTOCKS--Table of Contents



                      Subpart A_General Provisions

Sec.
1090.1 Applicability and relationship to other parts.
1090.5 Implementation dates.
1090.10 Contacting EPA.
1090.15 Confidential business information.
1090.20 Approval of submissions under this part.
1090.50 Rounding.
1090.55 Requirements for independent parties.
1090.80 Definitions.
1090.85 Explanatory terms.
1090.90 Acronyms and abbreviations.
1090.95 Incorporation by reference.

[[Page 514]]

   Subpart B_General Requirements and Provisions for Regulated Parties

1090.100 General provisions.
1090.105 Fuel manufacturers.
1090.110 Detergent blenders.
1090.115 Oxygenate blenders.
1090.120 Oxygenate producers.
1090.125 Certified butane producers.
1090.130 Certified butane blenders.
1090.135 Certified pentane producers.
1090.140 Certified pentane blenders.
1090.145 Transmix processors.
1090.150 Transmix blenders.
1090.155 Fuel additive manufacturers.
1090.160 Distributors, carriers, and resellers.
1090.165 Retailers and WPCs.
1090.170 Independent surveyors.
1090.175 Auditors.
1090.180 Pipeline operators.

                      Subpart C_Gasoline Standards

1090.200 Overview and general requirements.
1090.205 Sulfur standards.
1090.210 Benzene standards.
1090.215 Gasoline RVP standards.
1090.220 RFG standards.
1090.225 Anti-dumping standards.
1090.230 Limitation on use of gasoline-ethanol blends.
1090.250 Certified butane standards.
1090.255 Certified pentane standards.
1090.260 Gasoline deposit control standards.
1090.265 Gasoline additive standards.
1090.270 Gasoline oxygenate standards.
1090.275 Ethanol denaturant standards.
1090.285 RFG covered areas.
1090.290 Changes to RFG covered areas and procedures for opting out of 
          RFG.
1090.295 Procedures for relaxing the federal 7.8 psi RVP standard.

           Subpart D_Diesel Fuel and ECA Marine Fuel Standards

1090.300 Overview and general requirements.
1090.305 ULSD standards.
1090.310 Diesel fuel additives standards.
1090.315 Heating oil, kerosene, ECA marine fuel, and jet fuel 
          provisions.
1090.320 500 ppm LM diesel fuel standards.
1090.325 ECA marine fuel standards.

Subpart E [Reserved]

          Subpart F_Transmix and Pipeline Interface Provisions

1090.500 Gasoline produced from blending transmix into PCG.
1090.505 Gasoline produced from TGP.
1090.510 Diesel and distillate fuel produced from TDP.
1090.515 500 ppm LM diesel fuel produced from TDP.
1090.520 Handling practices for pipeline interface that is not transmix.

         Subpart G_Exemptions, Hardships, and Special Provisions

1090.600 General provisions.
1090.605 National security and military use exemptions.
1090.610 Temporary research, development, and testing exemptions.
1090.615 Racing and aviation exemptions.
1090.620 Exemptions for Guam, American Samoa, and the Commonwealth of 
          the Northern Mariana Islands.
1090.625 Exemptions for California gasoline and diesel fuel.
1090.630 Exemptions for Alaska, Hawaii, Puerto Rico, and the U.S. Virgin 
          Islands summer gasoline.
1090.635 Refinery extreme unforeseen hardship exemption.
1090.640 Exemptions from the gasoline deposit control requirements.
1090.645 Exemption for exports of fuels, fuel additives, and regulated 
          blendstocks.
1090.650 Distillate global marine fuel exemption.

          Subpart H_Averaging, Banking, and Trading Provisions

1090.700 Compliance with average standards.
1090.705 Facility level compliance.
1090.710 Downstream oxygenate accounting.
1090.715 Deficit carryforward.
1090.720 Credit use.
1090.725 Credit generation.
1090.730 Credit transfers.
1090.735 Invalid credits and remedial actions.
1090.740 Downstream BOB recertification.
1090.745 Informational annual average calculations.

                         Subpart I_Registration

1090.800 General provisions.
1090.805 Contents of registration.
1090.810 Voluntary cancellation of company or facility registration.
1090.815 Deactivation (involuntary cancellation) of registration.
1090.820 Changes of ownership.

                           Subpart J_Reporting

1090.900 General provisions.
1090.905 Annual, batch, and credit transaction reporting for gasoline 
          manufacturers.
1090.910 Reporting for gasoline manufacturers that recertify BOB to 
          gasoline.
1090.915 Batch reporting for oxygenate producers and importers.
1090.920 Reports by certified pentane producers.
1090.925 Reports by independent surveyors.
1090.930 Reports by auditors.
1090.935 Reports by diesel fuel manufacturers.

[[Page 515]]

              Subpart K_Batch Certification and Designation

1090.1000 Batch certification requirements.
1090.1005 Designation of batches of fuels, fuel additives, and regulated 
          blendstocks.
1090.1010 Designation requirements for gasoline and regulated 
          blendstocks.
1090.1015 Designation requirements for diesel and distillate fuels.
1090.1020 Batch numbering.

                  Subpart L_Product Transfer Documents

1090.1100 General requirements.
1090.1105 PTD requirements for exempt fuels.
1090.1110 PTD requirements for gasoline, gasoline additives, and 
          gasoline regulated blendstocks.
1090.1115 PTD requirements for distillate and residual fuels.
1090.1120 PTD requirements for diesel fuel additives.
1090.1125 Alternative PTD language.

                         Subpart M_Recordkeeping

1090.1200 General recordkeeping requirements.
1090.1205 Recordkeeping requirements for all regulated parties.
1090.1210 Recordkeeping requirements for gasoline manufacturers.
1090.1215 Recordkeeping requirements for diesel fuel, ECA marine fuel, 
          and distillate global marine fuel manufacturers.
1090.1220 Recordkeeping requirements for oxygenate blenders.
1090.1225 Recordkeeping requirements for gasoline additives.
1090.1230 Recordkeeping requirements for oxygenate producers.
1090.1235 Recordkeeping requirements for ethanol denaturant.
1090.1240 Recordkeeping requirements for gasoline detergent blenders.
1090.1245 Recordkeeping requirements for independent surveyors.
1090.1250 Recordkeeping requirements for auditors.
1090.1255 Recordkeeping requirements for transmix processors, transmix 
          blenders, transmix distributors, and pipeline operators.

               Subpart N_Sampling, Testing, and Retention

1090.1300 General provisions.

                            Scope of Testing

1090.1310 Testing to demonstrate compliance with standards.
1090.1315 In-line blending.
1090.1320 Adding blendstock to PCG.
1090.1325 Adding blendstock or PCG to TGP.
1090.1330 Preparing denatured fuel ethanol.

                     Handling and Preparing Samples

1090.1335 Collecting, preparing, and testing samples.
1090.1337 Demonstrating homogeneity.
1090.1340 Preparing a hand blend from BOB.
1090.1345 Retaining samples.

                         Measurement Procedures

1090.1350 Overview of test procedures.
1090.1355 Calculation adjustments and corrections.
1090.1360 Performance-based Measurement System.
1090.1365 Qualifying criteria for alternative measurement procedures.
1090.1370 Qualifying criteria for reference installations.
1090.1375 Quality control procedures.

               Testing Related to Gasoline Deposit Control

1090.1390 Requirement for Automated Detergent Blending Equipment 
          Calibration.
1090.1395 Gasoline deposit control test procedures.

                       Subpart O_Survey Provisions

1090.1400 General provisions.
1090.1405 National fuels survey program.
1090.1410 Independent surveyor requirements.
1090.1415 Survey program plan design requirements.
1090.1420 Additional requirements for E15 misfueling mitigation 
          surveying.
1090.1450 National sampling and testing oversight program.

     Subpart P_Retailer and Wholesale Purchaser-Consumer Provisions

1090.1500 Overview.

                                Labeling

1090.1510 E15 labeling provisions.
1090.1515 Diesel sulfur labeling provisions.

                           Refueling Hardware

1090.1550 Requirements for gasoline dispensing nozzles used with motor 
          vehicles.
1090.1555 Requirements for gasoline dispensing nozzles used primarily 
          with marine vessels.
1090.1560 Requirements related to dispensing natural gas.
1090.1565 Requirements related to dispensing liquefied petroleum gas.

               Subpart Q_Importer and Exporter Provisions

1090.1600 General provisions for importers.
1090.1605 Importation by marine vessel.

[[Page 516]]

1090.1610 Importation by rail or truck.
1090.1615 Gasoline treated as a blendstock.
1090.1650 General provisions for exporters.

             Subpart R_Compliance and Enforcement Provisions

1090.1700 Prohibited acts.
1090.1705 Evidence related to violations.
1090.1710 Penalties.
1090.1715 Liability provisions.
1090.1720 Affirmative defense provisions.

                    Subpart S_Attestation Engagements

1090.1800 General provisions.
1090.1805 Representative samples.
1090.1810 General procedures for gasoline manufacturers.
1090.1815 General procedures for gasoline importers.
1090.1820 Additional procedures for gasoline treated as blendstock.
1090.1825 Additional procedures for PCG used to produce gasoline.
1090.1830 Alternative procedures for certified butane blenders.
1090.1835 Alternative procedures for certified pentane blenders.
1090.1840 Additional procedures related to compliance with gasoline 
          average standards.
1090.1845 Procedures related to meeting performance-based measurement 
          and statistical quality control for test methods.
1090.1850 Procedures related to in-line blending waivers.

    Authority: 42 U.S.C. 7414, 7521, 7522-7525, 7541, 7542, 7543, 7545, 
7547, 7550, and 7601.

    Source: 85 FR 78469, Dec. 4, 2020, unless otherwise noted.



                      Subpart A_General Provisions



Sec.  1090.1  Applicability and relationship to other parts.

    (a) This part specifies fuel quality standards for gasoline and 
diesel fuel introduced into commerce in the United States. Additional 
requirements apply for fuel used in certain marine applications, as 
specified in paragraph (b) of this section.
    (1) The regulations include standards for fuel parameters that 
directly or indirectly affect vehicle, engine, and equipment emissions, 
air quality, and public health. The regulations also include standards 
and requirements for fuel additives and regulated blendstocks that are 
components of the fuels regulated under this part.
    (2) This part also specifies requirements for any person that 
engages in activities associated with the production, distribution, 
storage, and sale of fuels, fuel additives, and regulated blendstocks, 
such as collecting and testing samples for regulated parameters, 
reporting information to EPA to demonstrate compliance with fuel quality 
requirements, and performing other compliance measures to implement the 
standards. A party that produces and distributes other related products, 
such as heating oil, may need to meet certain reporting, recordkeeping, 
labeling, or other requirements of this part.
    (b)(1) The International Convention for the Prevention of Pollution 
from Ships, 1973 as modified by the Protocol of 1978 Annex VI (``MARPOL 
Annex VI'') is an international treaty that sets maximum sulfur content 
for fuel used in marine vessels, including separate standards for marine 
vessels navigating in a designated Emission Control Area (ECA). These 
standards and related requirements are specified in 40 CFR part 1043. 
This part also sets corresponding sulfur standards that apply to any 
person who produces or handles ECA marine fuel.
    (2) This part also includes requirements for parties involved in the 
production and distribution of IMO marine fuel, such as collecting and 
testing samples of fuels for regulated parameters, reporting information 
to EPA to demonstrate compliance with fuel quality requirements, and 
performing other compliance measures to implement the standards.
    (c) The requirements for the registration of fuel and fuel additives 
under 42 U.S.C. 7545(a), (b), and (e) are specified in 40 CFR part 79. A 
party that must meet the requirements of this part may also need to 
comply with the requirements for the registration of fuel and fuel 
additives under 40 CFR part 79.
    (d) The requirements for the Renewable Fuel Standard (RFS) are 
specified in 40 CFR part 80, subpart M. A party that must meet the 
requirements of this part may also need to comply with the requirements 
for the RFS program under 40 CFR part 80, subpart M.
    (e) Nothing in this part is intended to preempt the ability of state 
or local

[[Page 517]]

governments to control or prohibit any fuel or fuel additive for use in 
motor vehicles and motor vehicle engines that is not explicitly 
regulated by this part.



Sec.  1090.5  Implementation dates.

    (a) The provisions of this part apply beginning January 1, 2021, 
unless otherwise specified.
    (b) The following provisions of 40 CFR part 80 are applicable after 
December 31, 2020:
    (1) Gasoline sulfur and benzene credit balances and deficits from 
the 2020 compliance period carry forward for demonstrating compliance 
with requirements of this part. Any restrictions that apply to credits 
and deficits under 40 CFR part 80, such as a maximum credit life of 5 
years, continue to apply under this part.
    (2) Unless otherwise specified (e.g., in-line blending waivers for 
gasoline as specified in paragraph (b)(8) of this section), any approval 
granted under 40 CFR part 80 continues to be in effect under this part. 
For example, if EPA approved the use of an alternative label under 40 
CFR part 80, that approval continues to be valid under this part, 
subject to any conditions specified for the approval.
    (3) Unless otherwise specified, a regulated party must use the 
provisions of 40 CFR part 80 in 2021 to demonstrate compliance with 
regulatory requirements for the 2020 calendar year. This applies to 
calculating credits for the 2020 compliance period, and to any sampling, 
testing, reporting, and auditing related to fuels, fuel additives, and 
regulated blendstocks produced or imported in 2020.
    (4) Any testing to establish the precision and accuracy of 
alternative test procedures under 40 CFR part 80 continues to be valid 
under this part.
    (5) Requirements to keep records and retain fuel samples related to 
actions taken before January 1, 2021, continue to be in effect, as 
specified in 40 CFR part 80.
    (6) A party may comply with the PTD requirements of 40 CFR part 80 
instead of the requirements of subpart L of this part until May 1, 2021.
    (7) A party may comply with the automatic sampling provisions of 40 
CFR 80.8 instead of the requirements in Sec.  1090.1335(c) until January 
1, 2022.
    (8) A gasoline manufacturer may operate under an in-line blending 
waiver issued under 40 CFR part 80 until January 1, 2022, or until EPA 
approves a revised in-line blending waiver under Sec.  1090.1315, 
whichever is earlier. The following provisions apply:
    (i) A gasoline manufacturer operating under an in-line blending 
waiver under 40 CFR 80.65 must monitor and test for sulfur content, 
benzene content, and for summer gasoline, RVP, and may discontinue 
monitoring and testing for other properties that are included in their 
in-line blending waiver.
    (ii) The auditing requirements in Sec.  1090.1850 do not apply to an 
in-line blending waiver issued under 40 CFR part 80.
    (c) The following requirements apply for the 2021 compliance period:
    (1) The NSTOP specified in Sec.  1090.1450 must begin no later than 
June 1, 2021.
    (2) A gasoline manufacturer that accounts for oxygenate added 
downstream under Sec.  1090.710 is deemed compliant with the requirement 
to participate in the NSTOP specified in Sec.  1090.710(a)(3) until June 
1, 2021, if the gasoline manufacturer meets all other applicable 
requirements specified in Sec.  1090.710.
    (3) The independent surveyor conducting the NSTOP must submit the 
proof of contract required under Sec.  1090.1400(b) no later than April 
15, 2021.
    (4) The independent surveyor may collect only one summer or winter 
gasoline sample for each participating fuel manufacturing facility 
instead of the minimum two samples required under Sec.  
1090.1450(c)(2)(i).



Sec.  1090.10  Contacting EPA.

    A party must submit all reports, registrations, and documents for 
approval required under this part electronically to EPA using forms and 
procedures specified by EPA via the following website: https://
www.epa.gov/fuels-registration- reporting-and-compliance-help.

[[Page 518]]



Sec.  1090.15  Confidential business information.

    (a) Except as specified in paragraphs (b) through (d) of this 
section, any information submitted under this part claimed as 
confidential remains subject to evaluation by EPA under 40 CFR part 2, 
subpart B.
    (b) The following information contained in submissions under this 
part is not entitled to confidential treatment under 40 CFR part 2, 
subpart B or 5 U.S.C. 552(b)(4):
    (1) Submitter's name.
    (2) The name and location of the facility, if applicable.
    (3) The general nature of a request.
    (4) The relevant time period for a request, if applicable.
    (c) The following information incorporated into EPA determinations 
on submissions under this part is not entitled to confidential treatment 
under 40 CFR part 2, subpart B or 5 U.S.C. 552(b)(4):
    (1) Submitter's name.
    (2) The name and location of the facility, if applicable.
    (3) The general nature of a request.
    (4) The relevant time period for a request, if applicable.
    (5) The extent to which EPA either granted or denied the request and 
any relevant terms and conditions.
    (d)(1) The following information contained in any enforcement action 
taken under this part is not entitled to confidential treatment under 40 
CFR part 2, subpart B:
    (i) The company's name.
    (ii) The facility's name.
    (iii) Any EPA-issued company and facility identification numbers.
    (iv) The time or time period when any violation occurred.
    (v) The quantity of fuel, fuel additive, or regulated blendstock 
affected by the violation.
    (vi) Information relating to the exceedance of the fuel standard 
associated with the violation.
    (vii) Information relating to the generation, transfer, or use of 
credits associated with the violation.
    (viii) Any other information relevant to describing the violation.
    (2) Enforcement actions within the scope of paragraph (d)(1) of this 
section include notices of violation, settlement agreements, 
administrative complaints, civil complaints, criminal information, and 
criminal indictments.
    (e) EPA may disclose the information specified in paragraphs (b) 
through (d) of this section on its website, or otherwise make it 
available to interested parties, without additional notice, 
notwithstanding any claims that the information is entitled to 
confidential treatment under 40 CFR part 2, subpart B and 5 U.S.C. 
552(b)(4).

[85 FR 78469, Dec. 4, 2020, as amended at 87 FR 39677, July 1, 2022]



Sec.  1090.20  Approval of submissions under this part.

    (a) EPA may approve any submission required or allowed under this 
part if the request for approval satisfies all specified requirements.
    (b) EPA may impose terms and conditions on any approval of any 
submission required or allowed under this part.
    (c) EPA will deny any request for approval if the submission is 
incomplete, contains inaccurate or misleading information, or does not 
meet all specified requirements.
    (d) EPA may revoke any prior approval under this part for cause. For 
cause includes, but is not limited to, any of the following:
    (1) The approval has proved inadequate in practice.
    (2) The party fails to notify EPA if information that the approval 
was based on substantively changed after the approval was granted.
    (e) EPA may also revoke and void any approval under this part 
effective from the approval date for cause. Cause for voiding an 
approval includes, but is not limited to, any of the following:
    (1) The approval was not fully or diligently implemented.
    (2) The approval was based on false, misleading, or inaccurate 
information.
    (3) Failure of a party to fulfill or cause to be fulfilled any term 
or condition of an approval under this part.
    (f) Any person that has an approval revoked or voided under this 
part is liable for any resulting violation of the requirements of this 
part.

[[Page 519]]



Sec.  1090.50  Rounding.

    (a) Unless otherwise specified, round values to the number of 
significant digits necessary to match the number of decimal places of 
the applicable standard or specification. Perform all rounding as 
specified in 40 CFR 1065.20(e)(1) through (6). This convention is 
consistent with ASTM E29 and NIST SP 811.
    (b) Do not round intermediate values to transfer data unless the 
rounded number has at least 6 significant digits.
    (c) When calculating a specified percentage of a given value, the 
specified percentage is understood to have infinite precision. For 
example, if an allowable limit is specified as a fuel volume 
representing 1 percent of total volume produced, calculate the allowable 
volume by multiplying total volume by exactly 0.01.
    (d) Measurement devices that incorporate internal rounding may be 
used, consistent with the following provisions:
    (1) Devices may use any rounding convention if they report 6 or more 
significant digits.
    (2) Devices that report fewer than 6 significant digits may be used, 
consistent with the accuracy and repeatability specifications of the 
procedures specified in subpart N of this part.
    (e) Use one of the following rounding conventions for all batch 
volumes in a given compliance period, and for all reporting under this 
part:
    (1) Identify batch volume in gallons to the nearest whole gallon.
    (2)(i) Round batch volumes between 1,000 and 11,000 gallons to the 
nearest 10 gallons.
    (ii) Round batch volumes above 11,000 gallons to the nearest 100 
gallons.



Sec.  1090.55  Requirements for independent parties.

    This section specifies how a third party demonstrates their 
independence from the regulated party that hires them and their 
technical ability to perform the specified services.
    (a) Independence. The independent third party, their contractors, 
subcontractors, and their organizations must be independent of the 
regulated party. All the criteria listed in paragraphs (a)(1) and (2) of 
this section must be met by each person involved in the specified 
activities in this part that the independent third party is hired to 
perform for a regulated party, except that an internal auditor may 
instead meet the requirements in Sec.  1090.1800(b)(1)(i).
    (1) Employment criteria. No person employed by an independent third 
party, including contractor and subcontractor personnel, who is involved 
in a specified activity performed by the independent third party under 
the provisions of this part, may be employed, currently or previously, 
by the regulated party for any duration within the 12 months preceding 
the date when the regulated party hired the independent third party to 
provide services under this part.
    (2) Financial criteria. (i) The third-party's personnel, the third-
party's organization, or any organization or individual that may be 
contracted or subcontracted by the third party must meet all the 
following requirements:
    (A) Have received no more than one-quarter of their revenue from the 
regulated party during the year prior to the date of hire of the third 
party by the regulated party for any purpose.
    (B) Have no interest in the regulated party's business. Income 
received from the third party to perform specified activities under this 
part is excepted.
    (C) Not receive compensation for any specified activity in this part 
that is dependent on the outcome of the specified activity.
    (ii) The regulated party must be free from any interest in the 
third-party's business.
    (b) Technical ability. The third party must meet all the following 
requirements in order to demonstrate their technical capability to 
perform specified activities under this part:
    (1) An independent surveyor that conducts a survey under subpart O 
of this part must have personnel familiar with petroleum marketing, the 
sampling and testing of gasoline and diesel fuel at retail stations, and 
the designing of surveys to estimate compliance rates for fuel 
parameters nationwide. The independent surveyor must demonstrate this 
technical ability in plans submitted under subpart O of this part.

[[Page 520]]

    (2) A laboratory attempting to qualify alternative procedures must 
contract with an independent third party to verify the accuracy and 
precision of measured values as specified in Sec.  1090.1365. The 
independent third party must demonstrate work experience and a good 
working knowledge of the VCSB methods specified in Sec. Sec.  1090.1365 
and 1090.1370, with training and expertise corresponding to a bachelor's 
degree in chemical engineering, or combined bachelor's degrees in 
chemistry and statistics.
    (3) Any person auditing in-line blending operations must demonstrate 
work experience and be proficient in the VCSB methods specified in 
Sec. Sec.  1090.1365 and 1090.1370.
    (c) Suspension and disbarment. Any person suspended or disbarred 
under 40 CFR part 32 or 48 CFR part 9, subpart 9.4, is not qualified to 
perform review functions under this part.



Sec.  1090.80  Definitions.

    500 ppm LM diesel fuel means diesel fuel subject to the alternative 
sulfur standards in Sec.  1090.320 that is produced by a transmix 
processor under Sec.  1090.515.
    Additization means the addition of detergent to gasoline to create 
detergent-additized gasoline.
    Aggregated import facility means all import facilities within a PADD 
owned or operated by an importer and treated as a single fuel 
manufacturing facility in order to comply with the maximum benzene 
average standards under Sec.  1090.210(b).
    Anhydrous ethanol means ethanol that contains no more than 1.0 
volume percent water.
    Auditor means any person that conducts audits under subpart S of 
this part.
    Automated detergent blending facility means any facility (including, 
but not limited to, a truck or individual storage tank) at which 
detergents are blended with gasoline by means of an injector system 
calibrated to automatically deliver a specified amount of detergent.
    Average standard means a fuel standard applicable over a compliance 
period.
    Batch means a quantity of fuel, fuel additive, or regulated 
blendstock that has a homogeneous set of properties. This also includes 
fuel, fuel additive, or regulated blendstock for which homogeneity 
testing is not required under Sec.  1090.1337(a).
    Biodiesel means a diesel fuel composed of mono-alkyl esters made 
from nonpetroleum feedstocks.
    Blender pump means any fuel dispenser where PCG is blended with E85 
(made only with PCG and DFE) or DFE to produce gasoline that has an 
ethanol content greater than that of the PCG. A fuel dispenser that 
produces gasoline with anything other than PCG and DFE (e.g., natural 
gas liquids) is a fuel blending facility.
    Blending manufacturer means any person who owns, leases, operates, 
controls, or supervises a fuel blending facility in the United States.
    Blendstock means any liquid compound or mixture of compounds (not 
including fuel or fuel additive) that is used or intended for use as a 
component of a fuel.
    Business day means Monday through Friday, except the legal public 
holidays specified in 5 U.S.C. 6103 or any other day declared to be a 
holiday by federal statute or executive order.
    Butane means an organic compound with the formula 
C4H10.
    Butane blending facility means a fuel manufacturing facility where 
butane is blended into PCG.
    California diesel means diesel fuel designated by a diesel fuel 
manufacturer as for use in California.
    California gasoline means gasoline designated by a gasoline 
manufacturer as for use in California.
    Carrier means any distributor who transports or stores or causes the 
transportation or storage of fuel, fuel additive, or regulated 
blendstock without taking title to or otherwise having any ownership of 
the fuel, fuel additive, or regulated blendstock, and without altering 
either the quality or quantity of the fuel, fuel additive, or regulated 
blendstock.
    Category 1 (C1) marine vessel means a vessel that is propelled by an 
engine(s) that meets the definition of ``Category 1'' in 40 CFR part 
1042.901.

[[Page 521]]

    Category 2 (C2) marine vessel means a vessel that is propelled by an 
engine(s) that meets the definition of ``Category 2'' in 40 CFR part 
1042.901.
    Category 3 (C3) marine vessel means a vessel that is propelled by an 
engine(s) that meets the definition of ``Category 3'' in 40 CFR part 
1042.901.
    CBOB means a BOB produced or imported for use outside of an RFG 
covered area.
    Certified butane means butane that is certified to meet the 
requirements in Sec.  1090.250.
    Certified butane blender means a blending manufacturer that produces 
gasoline by blending certified butane into PCG and that uses the 
provisions of Sec.  1090.1320(b) to meet the applicable sampling and 
testing requirements.
    Certified butane producer means a regulated blendstock producer that 
certifies butane as meeting the requirements in Sec.  1090.250.
    Certified ethanol denaturant means ethanol denaturant that is 
certified to meet the requirements in Sec.  1090.275.
    Certified ethanol denaturant producer means any person that 
certifies ethanol denaturant as meeting the requirements in Sec.  
1090.275.
    Certified non-transportation 15 ppm distillate fuel or certified 
NTDF has the meaning given in 40 CFR 80.1401.
    Certified pentane means pentane that is certified to meet the 
requirements in Sec.  1090.255.
    Certified pentane blender means a blending manufacturer that 
produces gasoline by blending certified pentane into PCG and that uses 
the provisions of Sec.  1090.1320 to meet the applicable sampling and 
testing requirements.
    Certified pentane producer means a regulated blendstock producer 
that certifies pentane as meeting the requirements in Sec.  1090.255.
    Compliance period means the calendar year (January 1 through 
December 31).
    Conventional gasoline (CG) means gasoline that is not certified to 
meet the requirements for RFG in Sec.  1090.220.
    Crosscheck program means an arrangement for laboratories to perform 
measurements from test samples prepared from a single homogeneous fuel 
batch to establish an accepted reference value for evaluating accuracy 
of individual laboratories and measurement systems.
    Days means calendar days, including weekends and holidays.
    Denatured fuel ethanol (DFE) means anhydrous ethanol that contains a 
denaturant to make it unfit for human consumption, that is produced or 
imported for use in gasoline, and that meets the standards and 
requirements in Sec.  1090.270.
    Detergent means any chemical compound or combination of chemical 
compounds that is added to gasoline to control deposit formation and 
meets the requirements in Sec.  1090.260. Detergent may be part of a 
detergent additive package.
    Detergent additive package means an additive package containing 
detergent and may also contain carrier oils and non-detergent-active 
components such as corrosion inhibitors, antioxidants, metal 
deactivators, and handling solvents.
    Detergent blender means any person who owns, leases, operates, 
controls, or supervises the blending operation of a detergent blending 
facility, or imports detergent-additized gasoline.
    Detergent blending facility means any facility (including, but not 
limited to, a truck or individual storage tank) at which detergent is 
blended with gasoline.
    Detergent manufacturer means any person who owns, leases, operates, 
controls, or supervises a facility that produces detergent. A detergent 
manufacturer is a fuel additive manufacturer.
    Detergent-additized gasoline or detergent gasoline means any 
gasoline that contains a detergent.
    Diesel fuel means any of the following:
    (1) Any fuel commonly or commercially known as diesel fuel.
    (2) Any fuel (including NP diesel fuel or a fuel blend that contains 
NP diesel fuel) that is intended or used to power a vehicle or engine 
that is designed to operate using diesel fuel.
    (3) Any fuel that conforms to the specifications of ASTM D975 
(incorporated by reference in Sec.  1090.95) and is made available for 
use in a vehicle or engine designed to operate using diesel fuel.

[[Page 522]]

    Diesel fuel manufacturer means a fuel manufacturer that owns, 
leases, operates, controls, or supervises a fuel manufacturing facility 
where diesel fuel is produced or imported.
    Distillate fuel means diesel fuel and other petroleum fuels with a 
T90 temperature below 700 [deg]F that can be used in vehicles or engines 
that are designed to operate using diesel fuel. For example, diesel 
fuel, jet fuel, heating oil, No. 1 fuel (kerosene), No. 4 fuel, DMX, 
DMA, DMB, and DMC are distillate fuels. These specific fuel grades are 
identified in ASTM D975 and ISO 8217. Natural gas, LPG, and gasoline are 
not distillate fuels. T90 temperature is based on the distillation test 
method specified in Sec.  1090.1350.
    Distributor means any person who transports, stores, or causes the 
transportation or storage of fuel, fuel additive, or regulated 
blendstock at any point between any fuel manufacturing facility, fuel 
additive manufacturing facility, or regulated blendstock production 
facility and any retail outlet or WPC facility.
    Downstream location means any point in the fuel distribution system 
other than a fuel manufacturing facility through which the fuel passes 
after it leaves the fuel manufacturing facility gate at which it was 
certified (e.g., fuel at facilities of distributors, pipelines, 
terminals, carriers, retailers, oxygenate blenders, and WPCs).
    E0 means gasoline that contains no ethanol. This is also known as 
neat gasoline.
    E10 means gasoline that contains at least 9 and no more than 10 
volume percent ethanol.
    E15 means gasoline that contains more than 10 and no more than 15 
volume percent ethanol.
    E85 means a fuel that contains more than 50 volume percent but no 
more than 83 volume percent ethanol and is used, intended for use, or 
made available for use in flex-fuel vehicles or flex-fuel engines. E85 
is not gasoline.
    ECA marine fuel means diesel, distillate, or residual fuel used, 
intended for use, or made available for use in C3 marine vessels while 
the vessels are operating within an ECA, or an ECA associated area.
    Ethanol means an alcohol of the chemical formula 
C2H5OH.
    Ethanol denaturant means PCG, gasoline blendstocks, or natural gas 
liquids that are added to anhydrous ethanol to make the ethanol unfit 
for human consumption as required and defined in 27 CFR parts 19 through 
21.
    Facility means any place, or series of places, where any fuel, fuel 
additive, or regulated blendstock is produced, imported, blended, 
transported, distributed, stored, or sold.
    Flex-fuel engine has the same meaning as flexible-fuel engine in 40 
CFR 1054.801.
    Flex-fuel vehicle has the same meaning as flexible-fuel vehicle in 
40 CFR 86.1803-01.
    Fuel means only the fuels regulated under this part.
    Fuel additive means has the same meaning as additive in 40 CFR 
79.2(e).
    Fuel additive blender means any person who blends fuel additive into 
fuel in the United States, or any person who owns, leases, operates, 
controls, or supervises such an operation in the United States.
    Fuel additive manufacturer means any person who owns, leases, 
operates, controls, or supervises a facility where fuel additives are 
produced or imported into the United States.
    Fuel blending facility means any facility, other than a refinery or 
transmix processing facility, where fuel is produced by combining 
blendstocks or by combining blendstocks with fuel. Types of blending 
facilities include, but are not limited to, terminals, storage tanks, 
plants, tanker trucks, retail outlets, and marine vessels.
    Fuel dispenser means any apparatus used to dispense fuel into motor 
vehicles, nonroad vehicles, engines, equipment, or portable fuel 
containers (as defined in 40 CFR 59.680).
    Fuel manufacturer means any person who owns, leases, operates, 
controls, or supervises a fuel manufacturing facility. Fuel 
manufacturers include refiners, importers, blending manufacturers, and 
transmix processors.
    Fuel manufacturing facility means any facility where fuels are 
produced, imported, or recertified. Fuel manufacturing facilities 
include refineries, fuel blending facilities, transmix processing

[[Page 523]]

facilities, import facilities, and any facility where fuel is 
recertified.
    Fuel manufacturing facility gate means the point where the fuel 
leaves the fuel manufacturing facility at which the fuel manufacturer 
certified the fuel.
    Gasoline means any of the following:
    (1) Any fuel commonly or commercially known as gasoline, including 
BOB.
    (2) Any fuel intended or used to power a vehicle or engine designed 
to operate on gasoline.
    (3) Any fuel that conforms to the specifications of ASTM D4814 
(incorporated by reference in Sec.  1090.95) and is made available for 
use in a vehicle or engine designed to operate on gasoline.
    Gasoline before oxygenate blending (BOB) means gasoline for which a 
gasoline manufacturer has accounted for oxygenate added downstream under 
Sec.  1090.710. BOB is subject to all requirements and standards that 
apply to gasoline, unless subject to a specific alternative standard or 
requirement under this part.
    Gasoline manufacturer means a fuel manufacturer that owns, leases, 
operates, controls, or supervises a fuel manufacturing facility where 
gasoline is produced, imported, or recertified.
    Gasoline regulated blendstock means a regulated blendstock that is 
used or intended for use as a component of gasoline.
    Gasoline treated as blendstock (GTAB) means a gasoline regulated 
blendstock that is imported and used to produce gasoline as specified in 
Sec.  1090.1615.
    Global marine fuel means diesel fuel, distillate fuel, or residual 
fuel used, intended for use, or made available for use in steamships or 
Category 3 marine vessels while the vessels are operating in 
international waters or in any waters outside the boundaries of an ECA. 
Global marine fuel is subject to the provisions of MARPOL Annex VI. 
(Note: This part regulates global marine fuel only if it qualifies as a 
distillate fuel.)
    Heating oil means a combustible product that is used, intended for 
use, or made available for use in furnaces, boilers, or similar 
applications. Kerosene and jet fuel are not heating oil.
    IMO marine fuel means fuel that is ECA marine fuel or global marine 
fuel.
    Importer means any person who imports fuel, fuel additive, or 
regulated blendstock into the United States.
    Import facility means any facility where an importer imports fuel, 
fuel additive, or regulated blendstock.
    Independent surveyor means any person who meets the independence 
requirements in Sec.  1090.55 and conducts a survey under subpart O of 
this part.
    Intake valve deposits (IVD) means the deposits formed on the intake 
valve(s) of a gasoline-fueled engine during operation.
    Jet fuel means any distillate fuel used, intended for use, or made 
available for use in aircraft.
    Kerosene means any No. 1 distillate fuel that is used, intended for 
use, or made available for use as kerosene.
    Liquefied petroleum gas (LPG) means a liquid hydrocarbon fuel that 
is stored under pressure and is composed primarily of compounds that are 
gases at atmospheric conditions (temperature = 25 [deg]C and pressure = 
1 atm), excluding natural gas.
    Locomotive engine means an engine used in a locomotive as defined in 
40 CFR 92.2.
    Marine engine has the meaning given under 40 CFR 1042.901.
    Methanol means any fuel sold for use in motor vehicles and engines 
and commonly known or commercially sold as methanol or MXX, where XX 
represents the percent methanol (CH3OH) by volume.
    Natural gas means a fuel that is primarily composed of methane.
    Natural gas liquids (NGLs) means natural gasoline or other mixtures 
of hydrocarbons (primarily but not limited to propane, butane, pentane, 
hexane, and heptane) that are separated from the gaseous state of 
natural gas in the form of liquids at a facility, such as a natural gas 
production facility, gas processing plant, natural gas pipeline, 
refinery, or similar facility.
    Non-automated detergent blending facility means any facility 
(including a truck or individual storage tank) at which detergent 
additive is blended using a hand blending technique or any other non-
automated method.
    Nonpetroleum (NP) diesel fuel means renewable diesel fuel or 
biodiesel. NP

[[Page 524]]

diesel fuel also includes other renewable fuel under 40 CFR part 80, 
subpart M, that is used or intended for use to power a vehicle or engine 
that is designed to operate using diesel fuel or that is made available 
for use in a vehicle or engine designed to operate using diesel fuel.
    Oxygenate means a liquid compound that consists of one or more 
oxygenated compounds. Examples include DFE and isobutanol.
    Oxygenate blender means any person who adds oxygenate to gasoline in 
the United States, or any person who owns, leases, operates, controls, 
or supervises such an operation in the United States.
    Oxygenate blending facility means any facility (including but not 
limited to a truck) at which oxygenate is added to gasoline (including 
BOB), and at which the quality or quantity of gasoline is not altered in 
any other manner except for the addition of deposit control additives.
    Oxygenate import facility means any facility where oxygenate, 
including DFE, is imported into the United States.
    Oxygenate producer means any person who produces or imports 
oxygenate for gasoline in the United States, or any person who owns, 
leases, operates, controls, or supervises an oxygenate production or 
import facility in the United States.
    Oxygenate production facility means any facility where oxygenate is 
produced, including DFE.
    Oxygenated compound means an oxygen-containing, ashless organic 
compound, such as an alcohol or ether, which may be used as a fuel or 
fuel additive.
    PADD means Petroleum Administration for Defense District. These 
districts are the same as the PADDs used by other federal agencies, 
except for the addition of PADDs VI and VII. The individual PADDs are 
identified by region, state, and territory as follows:

------------------------------------------------------------------------
                                     Regional
             PADD                  description       State or territory
------------------------------------------------------------------------
I.............................  East Coast.......  Connecticut,
                                                    Delaware, District
                                                    of Columbia,
                                                    Florida, Georgia,
                                                    Maine, Maryland,
                                                    Massachusetts, New
                                                    Hampshire, New
                                                    Jersey, New York,
                                                    North Carolina,
                                                    Pennsylvania, Rhode
                                                    Island, South
                                                    Carolina, Vermont,
                                                    Virginia, West
                                                    Virginia.
II............................  Midwest..........  Illinois, Indiana,
                                                    Iowa, Kansas,
                                                    Kentucky, Michigan,
                                                    Minnesota, Missouri.
III...........................  Gulf Coast.......  Alabama, Arkansas,
                                                    Louisiana,
                                                    Mississippi, New
                                                    Mexico, Texas.
IV............................  Rocky Mountain...  Colorado, Idaho,
                                                    Montana, Utah,
                                                    Wyoming.
V.............................  West Coast.......  Alaska, Arizona,
                                                    California, Hawaii,
                                                    Nevada, Oregon,
                                                    Washington.
VI............................  Antilles.........  Puerto Rico, U.S.
                                                    Virgin Islands.
VII...........................  Pacific            American Samoa, Guam,
                                 Territories.       Northern Mariana
                                                    Islands.
------------------------------------------------------------------------

    Pentane means an organic compound with the formula 
C5H12.
    Pentane blending facility means a fuel manufacturing facility where 
pentane is blended into PCG.
    Per-gallon standard means the maximum or minimum value for any 
parameter that applies to every volume unit of a specified fuel, fuel 
additive, or regulated blendstock.
    Person has the meaning given in 42 U.S.C. 7602(e).
    Pipeline interface means the mixture between different fuels and 
products that abut each other during shipment by a refined petroleum 
products pipeline system.
    Pipeline operator means any person who owns, leases, operates, 
controls, or supervises a pipeline that transports fuel, fuel additive, 
or regulated blendstock in the United States.
    Previously certified gasoline (PCG) means CG, RFG, or BOB that has 
been certified as a batch by a gasoline manufacturer.
    Product transfer documents (PTDs) mean documents that reflect the 
transfer of title or physical custody of fuel, fuel additive, or 
regulated blendstock (e.g., invoices, receipts, bills of lading, 
manifests, pipeline tickets) between a transferor and a transferee.
    RBOB means a BOB produced or imported for use in an RFG covered 
area.
    Refiner means any person who owns, leases, operates, controls, or 
supervises a refinery in the United States.

[[Page 525]]

    Refinery means a facility where fuels are produced from feedstocks, 
including crude oil or renewable feedstocks, through physical or 
chemical processing equipment.
    Reformulated gasoline (RFG) means gasoline that is certified under 
Sec.  1090.1000(b) and that meets each of the standards and requirements 
in Sec.  1090.220.
    Regulated blendstock means certified butane, certified pentane, TGP, 
TDP, and GTAB.
    Regulated blendstock producer means any person who owns, leases, 
operates, controls, or supervises a facility where regulated blendstocks 
are produced or imported.
    Renewable diesel fuel means diesel fuel that is made from renewable 
(nonpetroleum) feedstocks and is not a mono-alkyl ester.
    Reseller means any person who purchases fuel identified by the 
corporate, trade, or brand name of a fuel manufacturer from such 
manufacturer or a distributor and resells or transfers it to a retailer 
or WPC, and whose assets or facilities are not substantially owned, 
leased, or controlled by such manufacturer.
    Residual fuel means a petroleum fuel with a T90 temperature at or 
above 700 [deg]F. For example, No. 5 fuels and No. 6 fuels are residual 
fuels. Residual fuel grades are specified in ASTM D396 and ISO 8217. T90 
temperature is based on the distillation test method specified in Sec.  
1090.1350.
    Responsible corporate officer (RCO) means a person who is authorized 
by the regulated party to make representations on behalf of, or obligate 
the company as ultimately responsible for, any activity regulated under 
this part (e.g., refining, importing, blending). An example is an 
officer of a corporation under the laws of incorporation of the state in 
which the company is incorporated. Examples of positions in non-
corporate business structures that qualify are owner, chief executive 
officer, president, or operations manager.
    Retail outlet means any establishment at which fuel is sold or 
offered for sale for use in motor vehicles, nonroad engines, nonroad 
vehicles, or nonroad equipment, including locomotive or marine engines.
    Retailer means any person who owns, leases, operates, controls, or 
supervises a retail outlet.
    RFG covered area means the geographic areas specified in Sec.  
1090.285 in which only RFG may be sold or dispensed to ultimate 
consumers.
    RFG opt-in area means an area that becomes a covered area under 42 
U.S.C. 7545(k)(6) as listed in Sec.  1090.285.
    Round (rounded, rounding) has the meaning given in Sec.  1090.50.
    Sampling strata means the three types of areas sampled during a 
survey, which include the following:
    (1) Densely populated areas.
    (2) Transportation corridors.
    (3) Rural areas.
    State Implementation Plan (SIP) means a plan approved or promulgated 
under 42 U.S.C. 7410 or 7502.
    Summer gasoline means gasoline that is subject to the RVP standards 
in Sec.  1090.215.
    Summer season or high ozone season means the period from June 1 
through September 15 for retailers and WPCs, and May 1 through September 
15 for all other persons, or an RVP control period specified in a SIP if 
it is longer.
    Tank truck means a truck used for transporting fuel, fuel additive, 
or regulated blendstock.
    Transmix means any of the following mixtures of fuels, which no 
longer meet the specifications for a fuel that can be used or sold as a 
fuel without further processing:
    (1) Pipeline interface that is not cut into the adjacent products.
    (2) Mixtures produced by unintentionally combining gasoline and 
distillate fuels.
    (3) Mixtures of gasoline and distillate fuel produced from normal 
business operations at terminals or pipelines, such as gasoline or 
distillate fuel drained from a tank or drained from piping or hoses used 
to transfer gasoline or distillate fuel to tanks or trucks, or gasoline 
or distillate fuel discharged from a safety relief valve that are 
segregated for further processing.
    Transmix blender means any person who owns, leases, operates, 
controls, or supervises a transmix blending facility.
    Transmix blending facility means any facility that produces gasoline 
by

[[Page 526]]

blending transmix into PCG under Sec.  1090.500.
    Transmix distillate product (TDP) means the diesel fuel blendstock 
that is produced when transmix is separated into blendstocks at a 
transmix processing facility.
    Transmix gasoline product (TGP) means the gasoline blendstock that 
is produced when transmix is separated into blendstocks at a transmix 
processing facility.
    Transmix processing facility means any facility that produces TGP or 
TDP from transmix by distillation or other refining processes, but does 
not produce gasoline or diesel fuel by processing crude oil or other 
products.
    Transmix processor means any person who owns, leases, operates, 
controls, or supervises a transmix processing facility. A transmix 
processor is a fuel manufacturer.
    Ultra low-sulfur diesel (ULSD) means diesel fuel that is certified 
to meet the standards in Sec.  1090.305.
    United States means the 50 states, the District of Columbia, the 
Commonwealth of Puerto Rico, the Commonwealth of the Northern Mariana 
Islands, Guam, American Samoa, and the U.S. Virgin Islands.
    Volume Additive Reconciliation (VAR) Period means the following:
    (1) For an automated detergent blending facility, the VAR period is 
a time period lasting no more than 31 days or until an adjustment to a 
detergent concentration rate that increases the initial rate by more 
than 10 percent, whichever occurs first. The concentration setting for a 
detergent injector may be adjusted by more than 10 percent above the 
initial rate without terminating the VAR Period, provided the purpose of 
the change is to correct a batch misadditization prior to the transfer 
of the batch to another party, or to correct an equipment malfunction 
and the concentration is immediately returned to no more than 10 percent 
above the initial rate of concentration after the correction.
    (2) For a non-automated detergent blending facility, the VAR Period 
constitutes the blending of one batch of gasoline.
    Voluntary consensus standards body (VCSB) means an organization that 
follows consistent protocols to adopt standards reflecting a wide range 
of input from interested parties. ASTM International and the 
International Organization for Standardization are examples of VCSB 
organizations.
    Wholesale purchaser-consumer (WPC) means any person that is an 
ultimate consumer of fuels and who purchases or obtains fuels for use in 
motor vehicles, nonroad vehicles, nonroad engines, or nonroad equipment, 
including locomotive or marine engines, and, in the case of liquid 
fuels, receives delivery of that product into a storage tank of at least 
550-gallon capacity substantially under the control of that person.
    Winter gasoline means gasoline that is not subject to the RVP 
standards in Sec.  1090.215.
    Winter season means any duration outside of the summer season or 
high ozone season.



Sec.  1090.85  Explanatory terms.

    This section explains how certain phrases and terms are used in this 
part, especially those used to clarify and explain regulatory 
provisions. They do not, however, constitute specific regulatory 
requirements and as such do not impose any compliance obligation on 
regulated parties.
    (a) Types of provisions. The term ``provision'' includes all aspects 
of the regulations in this part. As specified in this section, 
regulatory provisions include standards, requirements, and prohibitions, 
along with a variety of other types of provisions.
    (1) A standard is a limit on the formulation, components, or 
characteristics of any fuel, fuel additive, or regulated blendstock, 
established by regulation under this part. Compliance with or 
conformance to a standard is a specific type of requirement. Thus, a 
statement about the requirements of a part or section also applies with 
respect to the standards in the part or section. Examples of standards 
include the sulfur per-gallon standards for gasoline and diesel fuel.
    (2) While requirements state what someone must do, prohibitions 
state what someone must not do. Failing to meet any requirement that 
applies to a person under this part is a prohibited act.

[[Page 527]]

    (3) The regulations in this part include provisions that are not 
standards, requirements, or prohibitions, such as definitions.
    (b) Subject to. A fuel is considered ``subject to'' a specific 
provision if that provision applies, even if it falls within an 
exemption authorized under a different part of this regulation. For 
example, gasoline is subject to the provisions of this part even if it 
is exempt from the standards under subpart G of this part.
    (c) Singular and plural. Unless stated otherwise or unless it is 
clear from the regulatory context, provisions written in singular form 
include the plural form and provisions written in plural form include 
the singular form.
    (d) Inclusive lists. Lists in the regulations in this part prefaced 
by ``including'' or ``this includes'' are not exhaustive. The terms 
``including'' and ``this includes'' should be read to mean ``including 
but not limited to'' and ``this includes but is not limited to.''
    (e) Notes. Statements that begin with ``Note:'' or ``Note that'' are 
intended to clarify specific regulatory provisions stated elsewhere in 
the regulations in this part. By themselves, such statements are not 
intended to specify regulatory requirements.
    (f) Examples. Examples provided in the regulations in this part are 
typically introduced by either ``for example'' or ``such as.'' Specific 
examples given in the regulations do not necessarily represent the most 
common examples. The regulations may specify examples conditionally 
(that is, specifying that they are applicable only if certain criteria 
or conditions are met). Lists of examples are not exhaustive.



Sec.  1090.90  Acronyms and abbreviations.

------------------------------------------------------------------------
 
------------------------------------------------------------------------
500 ppm LM diesel fuel.......  As defined in Sec.   1090.80.
ABT..........................  averaging, banking, and trading.
ARV..........................  accepted reference value.
BOB..........................  gasoline before oxygenate blending.
CARB.........................  California Air Resources Board.
CFR..........................  Code of Federal Regulations.
CG...........................  conventional gasoline.
DFE..........................  denatured fuel ethanol.
E0...........................  As defined in Sec.   1090.80.
E10..........................  As defined in Sec.   1090.80.
E15..........................  As defined in Sec.   1090.80.
ECA marine fuel..............  As defined in Sec.   1090.80.
EPA..........................  Environmental Protection Agency.
GTAB.........................  gasoline treated as blendstock.
IMO marine fuel..............  As defined in Sec.   1090.80.
LAC..........................  lowest additive concentration.
LLOQ.........................  laboratory limit of quantitation.
MARPOL Annex VI..............  The International Convention for the
                                Prevention of Pollution from Ships, 1973
                                as modified by the Protocol of 1978
                                Annex VI.
NAAQS........................  National Ambient Air Quality Standard.
NARA.........................  National Archives and Records
                                Administration.
NFSP.........................  national fuels survey program.
NGL..........................  natural gas liquids.
NIST.........................  National Institute for Standards and
                                Technology.
NSTOP........................  national sampling and testing oversight
                                program.
PCG..........................  previously certified gasoline.
PLOQ.........................  published limit of quantitation.
ppm (mg/kg)..................  parts per million (or milligram per
                                kilogram).
PTD..........................  product transfer document.
R&D..........................  research and development.
RCO..........................  responsible corporate officer.
RFG..........................  reformulated gasoline.
RFS..........................  Renewable Fuel Standard.
RVP..........................  Reid vapor pressure.

[[Page 528]]

 
SIP..........................  state implementation plan.
SQC..........................  statistical quality control.
T10, T50, T90................  temperatures representing the points in a
                                distillation process where 10, 50, and
                                90 percent of the sample evaporates,
                                respectively.
TDP..........................  transmix distillate product.
TGP..........................  transmix gasoline product.
U.S..........................  United States.
U.S.C........................  United States Code.
ULSD.........................  ultra-low-sulfur diesel fuel.
VCSB.........................  voluntary consensus standards body.
------------------------------------------------------------------------



Sec.  1090.95  Incorporation by reference.

    (a) Certain material is incorporated by reference into this part 
with the approval of the Director of the Federal Register under 5 U.S.C. 
552(a) and 1 CFR part 51. All approved material is available for 
inspection at U.S. EPA, Air and Radiation Docket and Information Center, 
WJC West Building, Room 3334, 1301 Constitution Ave. NW, Washington, DC 
20460, (202) 566-1742, and is also available from the sources listed in 
this section. This material is also available for inspection at the 
National Archives and Records Administration (NARA). For information on 
the availability of this material at NARA, email [email protected], 
or go to www.archives.gov/federal-register /cfr/ibr-locations.html.
    (b) American Institute of Certified Public Accountants, 220 Leigh 
Farm Rd., Durham, NC 27707-8110, (888) 777-7077, or www.aicpa.org.
    (1) AICPA Code of Professional Conduct, updated through June 2020; 
IBR approved for Sec.  1090.1800(b).
    (2) Statements on Quality Control Standards (SQCS) No. 8, QC Section 
10: A Firm's System of Quality Control, current as of July 1, 2019; IBR 
approved for Sec.  1090.1800(b).
    (3) Statement on Standards for Attestation Engagements No. 18, 
Attestation Standards: Clarification and Recodification, Issued April 
2016; IBR approved for Sec.  1090.1800(b).
    (c) ASTM International, 100 Barr Harbor Dr., P.O. Box C700, West 
Conshohocken, PA 19428-2959, (877) 909-2786, or www.astm.org.
    (1) ASTM D86-20a, Standard Test Method for Distillation of Petroleum 
Products and Liquid Fuels at Atmospheric Pressure, approved July 1, 2020 
(``ASTM D86''); IBR approved for Sec.  1090.1350(b).
    (2) ASTM D287-12b (Reapproved 2019), Standard Test Method for API 
Gravity of Crude Petroleum and Petroleum Products (Hydrometer Method), 
approved December 1, 2019 (``ASTM D287''); IBR approved for Sec.  
1090.1337(d).
    (3) ASTM D975-20a, Standard Specification for Diesel Fuel, approved 
June 1, 2020 (``ASTM D975''); IBR approved for Sec.  1090.80.
    (4) ASTM D976-06 (Reapproved 2016), Standard Test Method for 
Calculated Cetane Index of Distillate Fuels, approved April 1, 2016 
(``ASTM D976''); IBR approved for Sec.  1090.1350(b).
    (5) ASTM D1298-12b (Reapproved 2017), Standard Test Method for 
Density, Relative Density, or API Gravity of Crude Petroleum and Liquid 
Petroleum Products by Hydrometer Method, approved July 15, 2017 (``ASTM 
D1298''); IBR approved for Sec.  1090.1337(d).
    (6) ASTM D1319-19, Standard Test Method for Hydrocarbon Types in 
Liquid Petroleum Products by Fluorescent Indicator Adsorption, approved 
August 1, 2019 (``ASTM D1319''); IBR approved for Sec.  1090.1350(b).
    (7) ASTM D2163-14 (Reapproved 2019), Standard Test Method for 
Determination of Hydrocarbons in Liquefied Petroleum (LP) Gases and 
Propane/Propene Mixtures by Gas Chromatography, approved May 1, 2019 
(``ASTM D2163''); IBR approved for Sec.  1090.1350(b).
    (8) ASTM D2622-16, Standard Test Method for Sulfur in Petroleum 
Products by Wavelength Dispersive X-ray Fluorescence Spectrometry, 
approved January 1, 2016 (``ASTM D2622''); IBR approved for Sec. Sec.  
1090.1350(b), 1090.1360(d), 1090.1365(b), and 1090.1375(c).

[[Page 529]]

    (9) ASTM D3120-08 (Reapproved 2019), Standard Test Method for Trace 
Quantities of Sulfur in Light Liquid Petroleum Hydrocarbons by Oxidative 
Microcoulometry, approved May 1, 2019 (``ASTM D3120''); IBR approved for 
Sec.  1090.1365(b).
    (10) ASTM D3231-18, Standard Test Method for Phosphorus in Gasoline, 
approved April 1, 2018 (``ASTM D3231''); IBR approved for Sec.  
1090.1350(b).
    (11) ASTM D3237-17, Standard Test Method for Lead in Gasoline by 
Atomic Absorption Spectroscopy, approved June 1, 2017 (``ASTM D3237''); 
IBR approved for Sec.  1090.1350(b).
    (12) ASTM D3606-20e1, Standard Test Method for Determination of 
Benzene and Toluene in Spark Ignition Fuels by Gas Chromatography, 
approved July 1, 2020 (``ASTM D3606''); IBR approved for Sec.  
1090.1360(c).
    (13) ASTM D4052-18a, Standard Test Method for Density, Relative 
Density, and API Gravity of Liquids by Digital Density Meter, approved 
December 15, 2018 (``ASTM D4052''); IBR approved for Sec.  1090.1337(d).
    (14) ASTM D4057-19, Standard Practice for Manual Sampling of 
Petroleum and Petroleum Products, approved July 1, 2019 (``ASTM 
D4057''); IBR approved for Sec. Sec.  1090.1335(b) and 1090.1605(b).
    (15) ASTM D4177-16e1, Standard Practice for Automatic Sampling of 
Petroleum and Petroleum Products, approved October 1, 2016 (``ASTM 
D4177''); IBR approved for Sec. Sec.  1090.1315(a) and 1090.1335(c).
    (16) ASTM D4737-10 (Reapproved 2016), Standard Test Method for 
Calculated Cetane Index by Four Variable Equation, approved July 1, 2016 
(``ASTM D4737''); IBR approved for Sec.  1090.1350(b).
    (17) ASTM D4806-20, Standard Specification for Denatured Fuel 
Ethanol for Blending with Gasolines for Use as Automotive Spark-Ignition 
Engine Fuel, approved May 1, 2020 (``ASTM D4806''); IBR approved for 
Sec.  1090.1395(a).
    (18) ASTM D4814-20a, Standard Specification for Automotive Spark-
Ignition Engine Fuel, approved April 1, 2020 (``ASTM D4814''); IBR 
approved for Sec. Sec.  1090.80 and 1090.1395(a).
    (19) ASTM D5134-13 (Reapproved 2017), Standard Test Method for 
Detailed Analysis of Petroleum Naphthas through n-Nonane by Capillary 
Gas Chromatography, approved October 1, 2017 (``ASTM D5134''); IBR 
approved for Sec.  1090.1350(b).
    (20) ASTM D5186-20, Standard Test Method for Determination of the 
Aromatic Content and Polynuclear Aromatic Content of Diesel Fuels By 
Supercritical Fluid Chromatography, approved July 1, 2020 (``ASTM 
D5186''); IBR approved for Sec.  1090.1350(b).
    (21) ASTM D5191-20, Standard Test Method for Vapor Pressure of 
Petroleum Products and Liquid Fuels (Mini Method), approved May 1, 2020 
(``ASTM D5191''); IBR approved for Sec. Sec.  1090.1360(d) and 
1090.1365(b).
    (22) ASTM D5453-19a, Standard Test Method for Determination of Total 
Sulfur in Light Hydrocarbons, Spark Ignition Engine Fuel, Diesel Engine 
Fuel, and Engine Oil by Ultraviolet Fluorescence, approved July 1, 2019 
(``ASTM D5453''); IBR approved for Sec.  1090.1350(b).
    (23) ASTM D5500-20a, Standard Test Method for Vehicle Evaluation of 
Unleaded Automotive Spark-Ignition Engine Fuel for Intake Deposit 
Formation, approved June 1, 2020 (``ASTM D5500''); IBR approved for 
Sec.  1090.1395(c).
    (24) ASTM D5599-18, Standard Test Method for Determination of 
Oxygenates in Gasoline by Gas Chromatography and Oxygen Selective Flame 
Ionization Detection, approved June 1, 2018 (``ASTM D5599''); IBR 
approved for Sec. Sec.  1090.1360(d) and 1090.1365(b).
    (25) ASTM D5769-20, Standard Test Method for Determination of 
Benzene, Toluene, and Total Aromatics in Finished Gasolines by Gas 
Chromatography/Mass Spectrometry, approved June 1, 2020 (``ASTM 
D5769''); IBR approved for Sec. Sec.  1090.1350(b), 1090.1360(d), and 
1090.1365(b).
    (26) ASTM D5842-19, Standard Practice for Sampling and Handling of 
Fuels for Volatility Measurement, approved November 1, 2019 (``ASTM 
D5842''); IBR approved for Sec.  1090.1335(d).
    (27) ASTM D5854-19a, Standard Practice for Mixing and Handling of 
Liquid Samples of Petroleum and Petroleum Products, approved May 1, 2019 
(``ASTM D5854''); IBR approved for Sec.  1090.1315(a).

[[Page 530]]

    (28) ASTM D6201-19a, Standard Test Method for Dynamometer Evaluation 
of Unleaded Spark-Ignition Engine Fuel for Intake Valve Deposit 
Formation, approved December 1, 2019 (``ASTM D6201''); IBR approved for 
Sec.  1090.1395(a).
    (29) ASTM D6259-15 (Reapproved 2019), Standard Practice for 
Determination of a Pooled Limit of Quantitation for a Test Method, 
approved May 1, 2019 (``ASTM D6259''); IBR approved for Sec.  
1090.1355(b).
    (30) ASTM D6299-20, Standard Practice for Applying Statistical 
Quality Assurance and Control Charting Techniques to Evaluate Analytical 
Measurement System Performance, approved May 1, 2020 (``ASTM D6299''); 
IBR approved for Sec. Sec.  1090.1370(c), 1090.1375(a), (b), and (c), 
and 1090.1450(c).
    (31) ASTM D6550-20, Standard Test Method for Determination of Olefin 
Content of Gasolines by Supercritical-Fluid Chromatography, approved 
July 1, 2020 (``ASTM D6550''); IBR approved for Sec.  1090.1350(b).
    (32) ASTM D6667-14 (Reapproved 2019), Standard Test Method for 
Determination of Total Volatile Sulfur in Gaseous Hydrocarbons and 
Liquefied Petroleum Gases by Ultraviolet Fluorescence, approved May 1, 
2019 (``ASTM D6667''); IBR approved for Sec. Sec.  1090.1360(d), 
1090.1365(b), and 1090.1375(c).
    (33) ASTM D6708-19a, Standard Practice for Statistical Assessment 
and Improvement of Expected Agreement Between Two Test Methods that 
Purport to Measure the Same Property of a Material, approved November 1, 
2019 (``ASTM D6708''); IBR approved for Sec. Sec.  1090.1360(c), 
1090.1365(d) and (f), and 1090.1375(c).
    (34) ASTM D6729-14, Standard Test Method for Determination of 
Individual Components in Spark Ignition Engine Fuels by 100 Metre 
Capillary High Resolution Gas Chromatography, approved October 1, 2014 
(``ASTM D6729''); IBR approved for Sec.  1090.1350(b).
    (35) ASTM D6730-19, Standard Test Method for Determination of 
Individual Components in Spark Ignition Engine Fuels by 100-Metre 
Capillary (with Precolumn) High-Resolution Gas Chromatography, approved 
July 1, 2019 (``ASTM D6730''); IBR approved for Sec.  1090.1350(b).
    (36) ASTM D6751-20, Standard Specification for Biodiesel Fuel Blend 
Stock (B100) for Middle Distillate Fuels, approved January 1, 2020 
(``ASTM D6751''); IBR approved for Sec.  1090.1350(b).
    (37) ASTM D6792-17, Standard Practice for Quality Management Systems 
in Petroleum Products, Liquid Fuels, and Lubricants Testing 
Laboratories, approved May 1, 2017 (``ASTM D6792''); IBR approved for 
Sec.  1090.1450(c).
    (38) ASTM D7039-15a (Reapproved 2020), Standard Test Method for 
Sulfur in Gasoline, Diesel Fuel, Jet Fuel, Kerosine, Biodiesel, 
Biodiesel Blends, and Gasoline-Ethanol Blends by Monochromatic 
Wavelength Dispersive X-ray Fluorescence Spectrometry, approved May 1, 
2020 (``ASTM D7039''); IBR approved for Sec.  1090.1365(b).
    (39) ASTM D7717-11 (Reapproved 2017), Standard Practice for 
Preparing Volumetric Blends of Denatured Fuel Ethanol and Gasoline 
Blendstocks for Laboratory Analysis, approved May 1, 2017 (``ASTM 
D7717''); IBR approved for Sec.  1090.1340(b).
    (40) ASTM D7777-13 (Reapproved 2018)e1, Standard Test Method for 
Density, Relative Density, or API Gravity of Liquid Petroleum by 
Portable Digital Density Meter, approved October 1, 2018 (``ASTM 
D7777''); IBR approved for Sec.  1090.1337(d).
    (d) Environmental Protection Agency, Air and Radiation Docket and 
Information Center, WJC West Building, Room 3334, 1301 Constitution Ave. 
NW, Washington, DC 20460, (202) 566-1742.
    (1) CARB Test Method, 13 CA ADC Sec.  2257; California Code of 
Regulations Title 13. Motor Vehicles, Division 3. Air Resources Board, 
Chapter 5. Standards for Motor Vehicle Fuels, Article 1. Standards for 
Gasoline, Subarticle 1. Gasoline Standards that Became Applicable Before 
1996, Sec.  2257. Required Additives in Gasoline; amendment filed May 
17, 1999.
    (2) [Reserved]
    (e) The Institute of Internal Auditors, 1035 Greenwood Blvd., Suite 
401, Lake Mary, FL 32746, (407) 937-1111, or www.theiia.org.
    (1) International Standards for the Professional Practice of 
Internal Auditing (Standards), Revised October 2016; IBR approved for 
Sec.  1090.1800(b).
    (2) [Reserved]

[[Page 531]]

    (f) National Institute of Standards and Technology, 100 Bureau Dr., 
Stop 1070, Gaithersburg, MD 20899-1070, (301) 975-6478, or www.nist.gov.
    (1) NIST Handbook 158, Field Sampling Procedures for Fuel and Motor 
Oil Quality Testing--A Handbook for Use by Fuel and Oil Quality 
Regulatory Officials, 2016 Edition, April 2016; IBR approved for Sec.  
1090.1410(b).
    (2) [Reserved]



   Subpart B_General Requirements and Provisions for Regulated Parties



Sec.  1090.100  General provisions.

    This subpart provides an overview of the general requirements and 
provisions applicable to any regulated party under this part. A person 
who meets the definition of more than one type of regulated party must 
comply with the requirements applicable to each of those types of 
regulated parties. For example, a fuel manufacturer that also transports 
fuel must meet the requirements applicable to a fuel manufacturer and a 
distributor. A regulated party is required to comply with all applicable 
requirements of this part, regardless of whether they are identified in 
this subpart. Any person that produces, sells, transfers, supplies, 
dispenses, or distributes fuel, fuel additive, or regulated blendstock 
must comply with all applicable requirements.
    (a) Recordkeeping. Any party that engages in activities that are 
regulated under this part must comply with recordkeeping requirements 
under subpart M of this part.
    (b) Compliance and enforcement. Any party that engages in activities 
that are regulated under this part is subject to compliance and 
enforcement provisions under subpart R of this part.
    (c) Hardships and exemptions. Some regulated parties under this part 
may be eligible, or eligible to petition, for a hardship or exemption 
under subpart G of this part.
    (d) In addition to the requirements of paragraphs (a) through (c) of 
this section and Sec.  1090.105, an importer must also comply with 
subpart Q of this part.



Sec.  1090.105  Fuel manufacturers.

    This section provides an overview of general requirements applicable 
to a fuel manufacturer. A gasoline manufacturer must comply with the 
requirements of paragraph (a) of this section. A diesel fuel or IMO 
marine fuel manufacturer must comply with the requirements of paragraph 
(b) of this section.
    (a) Gasoline manufacturers. Except as specified otherwise in this 
subpart, a gasoline manufacturer must comply with the following 
requirements:
    (1) Producing compliant gasoline. A gasoline manufacturer must 
produce or import gasoline that meets the standards of subpart C of this 
part and must comply with the ABT requirements in subpart H of this 
part.
    (2) Registration. A gasoline manufacturer must register with EPA 
under subpart I of this part.
    (3) Reporting. A gasoline manufacturer must submit reports to EPA 
under subpart J of this part.
    (4) Certification and designation. A gasoline manufacturer must 
certify and designate the gasoline they produce under subpart K of this 
part.
    (5) PTDs. On each occasion when a gasoline manufacturer transfers 
custody of or title to any gasoline, the transferor must provide to the 
transferee PTDs under subpart L of this part.
    (6) Sampling, testing, and sample retention. A gasoline manufacturer 
must conduct sampling, testing, and sample retention in accordance with 
subpart N of this part.
    (7) Surveys. A gasoline manufacturer may participate in applicable 
fuel surveys under subpart O of this part.
    (8) Annual attest engagement. A gasoline manufacturer must submit 
annual attest engagement reports to EPA under subpart S of this part.
    (b) Diesel fuel and IMO marine fuel manufacturers. A diesel fuel or 
IMO marine fuel manufacturer must comply with the following 
requirements, as applicable:
    (1) Producing compliant diesel fuel and ECA marine fuel. A diesel 
fuel or ECA marine fuel manufacturer must produce or import diesel fuel 
or ECA marine fuel that meets the requirements of subpart D of this 
part.

[[Page 532]]

    (2) Registration. A diesel fuel or ECA marine fuel manufacturer must 
register with EPA under subpart I of this part.
    (3) Reporting. A diesel fuel manufacturer must submit reports to EPA 
under subpart J of this part.
    (4) Certification and designation. A diesel fuel or ECA marine fuel 
manufacturer must certify and designate the diesel fuel or ECA marine 
fuel they produce under subpart K of this part. A distillate global 
marine fuel manufacturer must designate the distillate global marine 
fuel they produce under subpart K of this part.
    (5) PTDs. On each occasion when a diesel fuel or IMO marine fuel 
manufacturer transfers custody or title to any diesel fuel or IMO marine 
fuel, the transferor must provide to the transferee PTDs under subpart L 
of this part.
    (6) Sampling, testing, and retention requirements. A diesel fuel or 
ECA marine fuel manufacturer must conduct sampling, testing, and sample 
retention in accordance with subpart N of this part.
    (7) Surveys. A diesel fuel manufacturer may participate in 
applicable fuel surveys under subpart O of this part.
    (8) Distillate global marine fuel manufacturers. A distillate global 
marine fuel manufacturer does not need to comply with the requirements 
of paragraphs (b)(1) through (3), and (6) of this section for global 
marine fuel that is exempt from the standards in subpart D of this part, 
as specified in Sec.  1090.650.



Sec.  1090.110  Detergent blenders.

    A detergent blender must comply with the requirements of this 
section.
    (a) Gasoline standards. A detergent blender must comply with the 
applicable requirements of subpart C of this part.
    (b) PTDs. On each occasion when a detergent blender transfers 
custody of or title to any fuel, fuel additive, or regulated blendstock, 
the transferor must provide to the transferee PTDs under subpart L of 
this part.
    (c) Recordkeeping. A detergent blender must demonstrate compliance 
with the requirements in Sec.  1090.260(a) as specified in Sec.  
1090.1240.
    (d) Equipment calibration. A detergent blender at an automated 
detergent blending facility must calibrate their detergent blending 
equipment in accordance with subpart N of this part.



Sec.  1090.115  Oxygenate blenders.

    An oxygenate blender must comply with the requirements of this 
section.
    (a) Gasoline standards. An oxygenate blender must comply with the 
applicable requirements of subpart C of this part.
    (b) Registration. An oxygenate blender must register with EPA under 
subpart I of this part.
    (c) PTDs. On each occasion when an oxygenate blender transfers 
custody or title to any fuel, fuel additive, or regulated blendstock, 
the transferor must provide to the transferee PTDs under subpart L of 
this part.
    (d) Oxygenate blending requirements. An oxygenate blender must 
follow the blending instructions specified by the gasoline manufacturer 
under Sec.  1090.710(a)(5) unless the oxygenate blender recertifies BOBs 
under Sec.  1090.740.



Sec.  1090.120  Oxygenate producers.

    This section provides an overview of general requirements applicable 
to an oxygenate producer (e.g., a DFE or isobutanol producer). A DFE 
producer must comply with the requirements for an oxygenate producer in 
paragraph (a) of this section and the additional requirements specified 
in paragraph (b) of this section.
    (a) Oxygenate producers. An oxygenate producer must comply with the 
following requirements:
    (1) Gasoline standards. An oxygenate producer must comply with the 
applicable requirements of subpart C of this part.
    (2) Registration. An oxygenate producer must register with EPA under 
subpart I of this part.
    (3) Reporting. An oxygenate producer must submit reports to EPA 
under subpart J of this part.
    (4) Certification and designation. An oxygenate producer must 
certify and designate the oxygenate they produce under subpart K of this 
part.
    (5) PTDs. On each occasion when an oxygenate producer transfers 
custody

[[Page 533]]

or title to any fuel, fuel additive, or regulated blendstock, the 
transferor must provide to the transferee PTDs under subpart L of this 
part.
    (6) Sampling, testing, and retention requirements. An oxygenate 
producer must conduct sampling, testing, and sample retention in 
accordance with subpart N of this part.
    (b) DFE producers. In addition to the requirements specified in 
paragraph (a) of this section, a DFE producer must meet all the 
following requirements:
    (1) Use denaturant that complies with the requirements specified in 
Sec. Sec.  1090.270(b) and 1090.275.
    (2) Participate in a survey program conducted by an independent 
surveyor under subpart O of this part if the DFE producer produces DFE 
made available for use in the production of E15.



Sec.  1090.125  Certified butane producers.

    A certified butane producer must comply with the requirements of 
this section.
    (a) Gasoline standards. A certified butane producer must comply with 
the applicable requirements of subpart C of this part.
    (b) Certification and designation. A certified butane producer must 
certify and designate the certified butane they produce under subpart K 
of this part.
    (c) PTDs. On each occasion when a certified butane producer 
transfers custody of or title to any certified butane, the transferor 
must provide to the transferee PTDs under subpart L of this part.
    (d) Sampling, testing, and retention requirements. A certified 
butane producer must conduct sampling, testing, and sample retention in 
accordance with subpart N of this part.



Sec.  1090.130  Certified butane blenders.

    A certified butane blender that blends certified butane into PCG is 
a gasoline manufacturer that may comply with the requirements of this 
section in lieu of the requirements in Sec.  1090.105.
    (a) Gasoline standards. A certified butane blender must comply with 
the applicable requirements of subpart C of this part.
    (b) Registration. A certified butane blender must register with EPA 
under subpart I of this part.
    (c) Reporting. A certified butane blender must submit reports to EPA 
under subpart J of this part.
    (d) PTDs. When certified butane is blended with PCG, PTDs that 
accompany the gasoline blended with certified butane must comply with 
subpart L of this part.
    (e) Sampling and testing requirements. A certified butane blender 
must comply with the alternative sampling and testing approach in Sec.  
1090.1320(b).
    (f) Survey. A certified butane blender may participate in the 
applicable fuel surveys of subpart O of this part.
    (g) Annual attest engagement. A certified butane blender must submit 
annual attest engagement reports to EPA under subpart S of this part.



Sec.  1090.135  Certified pentane producers.

    A certified pentane producer must comply with the requirements of 
this section.
    (a) Gasoline standards. A certified pentane producer must comply 
with the applicable requirements of subpart C of this part.
    (b) Registration. A certified pentane producer must register with 
EPA under subpart I of this part.
    (c) Reporting. A certified pentane producer must submit reports to 
EPA under subpart J of this part.
    (d) Certification and designation. A certified pentane producer must 
certify and designate the certified pentane they produce under subpart K 
of this part.
    (e) PTDs. On each occasion when a certified pentane producer 
transfers custody of or title to any certified pentane, the transferor 
must provide to the transferee PTDs under subpart L of this part.
    (f) Sampling, testing, and retention requirements. A certified 
pentane producer must conduct sampling, testing, and sample retention in 
accordance with subpart N of this part.



Sec.  1090.140  Certified pentane blenders.

    A certified pentane blender that blends certified pentane into PCG 
is a

[[Page 534]]

gasoline manufacturer that may comply with the requirements of this 
section in lieu of the requirements in Sec.  1090.105.
    (a) Gasoline standards. A certified pentane blender must comply with 
the applicable requirements of subpart C of this part.
    (b) Registration. A certified pentane blender must register with EPA 
under subpart I of this part.
    (c) Reporting. A certified pentane blender must submit reports to 
EPA under subpart J of this part.
    (d) PTDs. When certified pentane is blended with PCG, PTDs that 
accompany the gasoline blended with pentane must comply with subpart L 
of this part.
    (e) Sampling, testing, and retention requirements. A certified 
pentane blender must comply with the alternative sampling and testing 
approach in Sec.  1090.1320(b).
    (f) Survey. A certified pentane blender may participate in the 
applicable fuel surveys of subpart O of this part.
    (g) Annual attest engagement. A certified pentane blender must 
submit annual attest engagement reports to EPA under subpart S of this 
part.



Sec.  1090.145  Transmix processors.

    A transmix processor must comply with the requirements of this 
section.
    (a) Transmix requirements. A transmix processor must comply with the 
transmix requirements of subpart F of this part.
    (b) Registration. A transmix processor must register with EPA under 
subpart I of this part.
    (c) Certification and designation. A transmix processor must certify 
and designate the fuel they produce under subpart K of this part.
    (d) PTDs. On each occasion when a transmix processor produces a 
batch of fuel or transfers custody of or title to any fuel, fuel 
additive, or regulated blendstock, the transferor must provide to the 
transferee PTDs under subpart L of this part.
    (e) Sampling, testing, and retention requirements. A transmix 
processor must conduct sampling, testing, and sample retention in 
accordance with subparts F and N of this part.
    (f) Reporting. A transmix processor must submit reports to EPA under 
subpart J of this part.
    (g) Annual attest engagement. A transmix processor must submit 
annual attest engagement reports to EPA under subpart S of this part.



Sec.  1090.150  Transmix blenders.

    A transmix blender must comply with the requirements of this 
section.
    (a) Transmix requirements. A transmix blender must comply with the 
transmix requirements of subpart F of this part.
    (b) PTDs. On each occasion when a transmix blender produces a batch 
of fuel or transfers custody or title to any fuel, fuel additive, or 
regulated blendstock, the transferor must provide to the transferee PTDs 
under subpart L of this part.
    (c) Sampling, testing, and retention requirements. A transmix 
blender must conduct sampling, testing, and sample retention in 
accordance with subparts F and N of this part.



Sec.  1090.155  Fuel additive manufacturers.

    This section provides an overview of general requirements applicable 
to a fuel additive manufacturer. A gasoline additive manufacturer must 
comply with the requirements of paragraph (a) of this section. A diesel 
fuel additive manufacturer must comply with the requirements of 
paragraph (b) of this section. A certified ethanol denaturant producer 
must comply with the requirements of paragraph (c) of this section.
    (a) Gasoline additive manufacturers. A gasoline additive 
manufacturer must meet the following requirements:
    (1) Gasoline additive standards. A gasoline additive manufacturer 
must produce gasoline additives that comply with subpart C of this part.
    (2) Certification. A gasoline additive manufacturer must certify the 
gasoline additives they produce under subpart K of this part.
    (3) PTDs. On each occasion when a gasoline additive manufacturer 
transfers custody of or title to any gasoline additive, the transferor 
must provide to the transferee PTDs under subpart L of this part.

[[Page 535]]

    (4) Gasoline detergent manufacturers. A gasoline detergent 
manufacturer must comply with the following requirements:
    (i) Part 79 registration and LAC determination. A gasoline detergent 
manufacturer must register gasoline detergent(s) under 40 CFR 79.21 at a 
concentration that is greater than or equal to the LAC reported by the 
gasoline detergent manufacturer under 40 CFR 79.21(j). Note: EPA 
provides a list on EPA's website of detergents that have been certified 
by the gasoline detergent manufacturer as meeting the deposit control 
requirement (Search for ``List of Certified Detergent Additives'').
    (ii) Gasoline detergent standards. Report the LAC determined under 
Sec.  1090.260(b) and provide specific composition information as part 
of the gasoline detergent manufacturer's registration of the detergent 
under 40 CFR 79.21(j).
    (iii) PTDs. On each occasion when a gasoline detergent manufacturer 
transfers custody of or title to any gasoline detergent, the transferor 
must provide to the transferee PTDs under subpart L of this part.
    (iv) Sampling, testing, and retention requirements. A gasoline 
detergent manufacturer that registers detergents must conduct sampling, 
testing, and sample retention in accordance with subpart N of this part.
    (b) Diesel fuel additive manufacturers. A diesel fuel additive 
manufacturer must meet the following requirements:
    (1) Diesel fuel additive standards. A diesel fuel additive 
manufacturer must produce diesel fuel additives that comply with subpart 
D of this part.
    (2) Certification. A diesel fuel additive manufacturer must certify 
the diesel fuel additives they produce under subpart K of this part.
    (3) PTDs. On each occasion when a diesel fuel additive manufacturer 
transfers custody of or title to any diesel additive, the transferor 
must provide to the transferee PTDs under subpart L of this part.
    (c) Certified ethanol denaturant producers and importers. A 
certified ethanol denaturant producer or importer must meet the 
following requirements:
    (1) Certification. A certified ethanol denaturant producer or 
importer must certify that certified ethanol denaturant meets the 
requirements in Sec.  1090.275 using the procedures specified at Sec.  
1090.1000(g).
    (2) Registration. A certified ethanol denaturant producer or 
importer must register with EPA under subpart I of this part.
    (3) PTDs. On each occasion when a certified ethanol denaturant 
producer transfers custody or title to any fuel, fuel additive, or 
regulated blendstock, the transferor must provide to the transferee PTDs 
under subpart L of this part.



Sec.  1090.160  Distributors, carriers, and resellers.

    A distributor, carrier, or reseller must comply with the 
requirements of this section.
    (a) Gasoline and diesel standards. A distributor, carrier, or 
reseller must comply with the applicable requirements of subparts C and 
D of this part.
    (b) Registration. A distributor or carrier must register with EPA 
under subpart I of this part if they are part of the 500 ppm LM diesel 
fuel distribution chain under a compliance plan submitted under Sec.  
1090.515(g).
    (c) PTDs. On each occasion when a distributor, carrier, or reseller 
transfers custody or title to any fuel, fuel additive, or regulated 
blendstock, the transferor must provide to the transferee PTDs under 
subpart L of this part.



Sec.  1090.165  Retailers and WPCs.

    A retailer or WPC must comply with the requirements of this section.
    (a) Gasoline and diesel standards. A retailer or WPC must comply 
with the applicable requirements of subparts C and D of this part.
    (b) Labeling. A retailer or WPC that dispenses fuels requiring a 
label under this part must display fuel labels under subpart P of this 
part.
    (c) Fuels made through fuel dispensers. A retailer or WPC that 
produces gasoline (e.g., E15) through a fuel dispenser with anything 
other than PCG and DFE is also a blending manufacturer and must comply 
with the applicable requirements in Sec.  1090.105.

[[Page 536]]



Sec.  1090.170  Independent surveyors.

    An independent surveyor that conducts fuel surveys must comply with 
the requirements of this section.
    (a) Survey provisions. An independent surveyor must conduct fuel 
surveys under subpart O of this part.
    (b) Registration. An independent surveyor must register with EPA 
under subpart I of this part.
    (c) Reporting. An independent surveyor must submit reports to EPA 
under subpart J of this part.
    (d) Sampling, testing, and retention requirements. An independent 
surveyor must conduct sampling, testing, and sample retention in 
accordance with subpart N of this part.
    (e) Independence requirements. In order to perform a survey program 
under subpart O of this part, an independent surveyor must meet the 
independence requirements in Sec.  1090.55.



Sec.  1090.175  Auditors.

    An auditor that conducts an audit for a responsible party under this 
part must comply with the requirements of this section.
    (a) Registration. An auditor must register with EPA under subpart I 
of this part.
    (b) Reporting. An auditor must submit reports to EPA under subpart J 
of this part.
    (c) Attest engagement. An auditor must conduct audits under subpart 
S of this part.
    (d) Independence requirements. In order to perform an annual attest 
engagement under subpart S of this part, an auditor must meet the 
independence requirements in Sec.  1090.55 unless they are a certified 
internal auditor under Sec.  1090.1800(b)(1)(i).



Sec.  1090.180  Pipeline operators.

    A pipeline operator must comply with the requirements of this 
section.
    (a) Gasoline and diesel standards. A pipeline operator must comply 
with the applicable requirements of subparts C and D of this part.
    (b) PTDs. On each occasion when a pipeline operator transfers 
custody or title to any fuel, fuel additive, or regulated blendstock, 
the transferor must provide to the transferee PTDs under subpart L of 
this part.
    (c) Transmix requirements. A pipeline operator must comply with all 
applicable requirements in subpart F of this part.



                      Subpart C_Gasoline Standards



Sec.  1090.200  Overview and general requirements.

    (a) Except as specified in subpart G of this part, gasoline, 
gasoline additives, and gasoline regulated blendstocks are subject to 
the standards in this subpart.
    (b) Except for the sulfur average standard in Sec.  1090.205(a) and 
the benzene average standards in Sec.  1090.210(a) and (b), the 
standards in this part apply to gasoline, gasoline additives, and 
gasoline regulated blendstocks on a per-gallon basis. A gasoline 
manufacturer, gasoline additive manufacturer (e.g., an oxygenate or 
certified ethanol denaturant producer), or gasoline regulated blendstock 
producer (e.g., a certified butane or certified pentane producer) must 
demonstrate compliance with the per-gallon standards in this subpart by 
measuring fuel parameters in accordance with subpart N of this part.
    (c)(1) Except as specified in paragraph (c)(2) of this section, the 
sulfur average standard in Sec.  1090.205(a) and the benzene average 
standards in Sec.  1090.210(a) and (b) apply to all gasoline produced or 
imported by a fuel manufacturer during a compliance period. A fuel 
manufacturer must demonstrate compliance with average standards by 
measuring fuel parameters in accordance with subpart N of this part and 
by determining compliance under subpart H of this part.
    (2) The sulfur average standard in Sec.  1090.205(a) and the benzene 
average standards in Sec.  1090.210(a) and (b) do not apply to gasoline 
produced by the following:
    (i) Truck and rail importers using the provisions of Sec.  1090.1610 
to meet the alternative per-gallon standards of Sec. Sec.  1090.205(d) 
and 1090.210(c).
    (ii) Certified butane blenders.
    (iii) Certified pentane blenders.
    (iv) Transmix blenders.
    (v) Transmix processors that produce gasoline from only TGP or both 
TGP and PCG.

[[Page 537]]

    (d) No person may produce, import, sell, offer for sale, distribute, 
offer to distribute, supply, offer for supply, dispense, store, 
transport, or introduce into commerce any gasoline, gasoline additive, 
or gasoline regulated blendstock that does not comply with any per-
gallon standard set forth in this subpart.
    (e) No person may sell, offer for sale, supply, offer for supply, 
dispense, transport, or introduce into commerce for use as fuel in any 
motor vehicle (as defined in Section 216(2) of the Clean Air Act, 42 
U.S.C. 7550(2)) any gasoline that is produced with the use of additives 
containing lead, that contains more than 0.05 gram of lead per gallon, 
or that contains more than 0.005 grams of phosphorous per gallon.
    (f) No fuel or fuel additive manufacturer may introduce into 
commerce gasoline or gasoline additives (including oxygenates) that are 
not ``substantially similar'' under 42 U.S.C. 7545(f)(1) or permitted 
under a waiver granted under 42 U.S.C. 7545(f)(4).



Sec.  1090.205  Sulfur standards.

    Except as specified in subpart G of this part, all gasoline is 
subject to the following sulfur standards:
    (a) Sulfur average standard. A gasoline manufacturer must meet a 
sulfur average standard of 10.00 ppm for each compliance period.
    (b) Fuel manufacturing facility gate sulfur per-gallon standard. 
Gasoline at any fuel manufacturing facility gate is subject to a maximum 
sulfur per-gallon standard of 80 ppm. A gasoline manufacturer must not 
account for the downstream addition of oxygenates in determining 
compliance with this standard.
    (c) Downstream location sulfur per-gallon standard. Gasoline at any 
downstream location is subject to a maximum sulfur per-gallon standard 
of 95 ppm.
    (d) Sulfur standard for importers that import gasoline by rail or 
truck. (1) An importer that imports gasoline by rail or truck under 
Sec.  1090.1610 must comply with a maximum sulfur per-gallon standard of 
10 ppm instead of the standards in paragraphs (a) through (c) of this 
section.
    (2) An importer that imports gasoline by rail or truck but does not 
comply with the alternative sampling and testing requirements in Sec.  
1090.1610 must conduct sampling, testing, and sample retention in 
accordance with subpart N of this part and comply with the sulfur 
standards in paragraphs (a) and (b) of this section.



Sec.  1090.210  Benzene standards.

    Except as specified in subpart G of this part, all gasoline is 
subject to the following benzene standards:
    (a) Benzene average standard. A gasoline manufacturer must meet a 
benzene average standard of 0.62 volume percent for each compliance 
period.
    (b) Maximum benzene average standard. A gasoline manufacturer must 
meet a maximum benzene average standard of 1.30 volume percent without 
the use of credits for each compliance period.
    (c) Benzene standard for importers that import gasoline by rail or 
truck. (1) An importer that imports gasoline by rail or truck under 
Sec.  1090.1610 must comply with a 0.62 volume percent benzene per-
gallon standard instead of the standards in paragraphs (a) and (b) of 
this section.
    (2) An importer that imports gasoline by rail or truck that does not 
comply with the alternative sampling and testing requirements in Sec.  
1090.1610 must conduct sampling, testing, and sample retention in 
accordance with subpart N of this part and comply with the benzene 
standards in paragraphs (a) and (b) of this section.



Sec.  1090.215  Gasoline RVP standards.

    Except as specified in subpart G of this part and paragraph (c) of 
this section, all gasoline designated as summer gasoline or located at 
any location in the United States during the summer season is subject to 
a maximum RVP per-gallon standard in this section.
    (a)(1) Federal 9.0 psi maximum RVP per-gallon standard. Gasoline 
designated as summer gasoline or located at any location in the United 
States during the summer season must meet a maximum RVP per-gallon 
standard of 9.0 psi unless the gasoline is subject to one of the lower 
maximum RVP per-

[[Page 538]]

gallon standards specified in paragraphs (a)(2) through (5) of this 
section.
    (2) Federal 7.8 maximum RVP per-gallon standard. Gasoline designated 
as 7.8 psi summer gasoline, or located in the following areas during the 
summer season, must meet a maximum RVP per-gallon standard of 7.8 psi:

         Table 1 to Paragraph (a)(2)--Federal 7.8 psi RVP Areas
------------------------------------------------------------------------
       Area designation               State               Counties
------------------------------------------------------------------------
Denver-Boulder-Greeley-Ft.      Colorado.........  Adams Arapahoe,
 Collins-Loveland.                                  Boulder, Broomfield,
                                                    Denver, Douglas,
                                                    Jefferson, Larimer,
                                                    \1\ Weld.\2\
Reno..........................  Nevada...........  Washoe.
Portland......................  Oregon...........  Clackamas (only the
                                                    Air Quality
                                                    Maintenance Area),
                                                    Multnomah (only the
                                                    Air Quality
                                                    Maintenance Area),
                                                    Washington (only the
                                                    Air Quality
                                                    Maintenance Area).
Salem.........................  Oregon...........  Marion (only the
                                                    Salem Area
                                                    Transportation
                                                    Study), Polk (only
                                                    the Salem Area
                                                    Transportation
                                                    Study).
Beaumont-Port Arthur..........  Texas............  Hardin, Jefferson,
                                                    Orange.
Salt Lake City................  Utah.............  Davis, Salt Lake.
------------------------------------------------------------------------
\1\ That portion of Larimer County, CO that lies south of a line
  described as follows: Beginning at a point on Larimer County's eastern
  boundary and Weld County's western boundary intersected by 40 degrees,
  42 minutes, and 47.1 seconds north latitude, proceed west to a point
  defined by the intersection of 40 degrees, 42 minutes, 47.1 seconds
  north latitude and 105 degrees, 29 minutes, and 40.0 seconds west
  longitude, thence proceed south on 105 degrees, 29 minutes, 40.0
  seconds west longitude to the intersection with 40 degrees, 33 minutes
  and 17.4 seconds north latitude, thence proceed west on 40 degrees, 33
  minutes, 17.4 seconds north latitude until this line intersects
  Larimer County's western boundary and Grand County's eastern boundary.
  (Includes part of Rocky Mtn. Nat. Park.)
\2\ That portion of Weld County, CO that lies south of a line described
  as follows: Beginning at a point on Weld County's eastern boundary and
  Logan County's western boundary intersected by 40 degrees, 42 minutes,
  47.1 seconds north latitude, proceed west on 40 degrees, 42 minutes,
  47.1 seconds north latitude until this line intersects Weld County's
  western boundary and Larimer County's eastern boundary.

    (3) RFG maximum RVP per-gallon standard. Gasoline designated as 
Summer RFG or located in an RFG covered area during the summer season 
must meet a maximum RVP per-gallon standard of 7.4 psi.
    (4) California gasoline. Gasoline designated as California gasoline 
or used in areas subject to the California reformulated gasoline 
regulations must comply with those regulations under Title 13, 
California Code of Regulations, sections 2250-2273.5.
    (5) SIP-controlled gasoline. Gasoline designated as SIP-controlled 
gasoline or used in areas subject to a SIP-approved state fuel rule that 
requires an RVP of less than 9.0 psi must meet the requirements of the 
federally approved SIP.
    (b) Ethanol 1.0 psi waiver. (1) Except as specified in paragraph 
(b)(3) of this section, any gasoline subject to a federal 9.0 psi or 7.8 
psi maximum RVP per-gallon standard in paragraph (a)(1) or (2) of this 
section that meets the requirements of paragraph (b)(2) of this section 
is not in violation of this section if its RVP does not exceed the 
applicable standard by more than 1.0 psi.
    (2) To qualify for the special regulatory treatment specified in 
paragraph (b)(1) of this section, gasoline must meet the applicable RVP 
per-gallon standard in paragraph (a)(1) or (2) of this section prior to 
the addition of ethanol and must contain ethanol at a concentration of 
at least 9 volume percent and no more than 15 volume percent.
    (3) RFG and SIP-controlled gasoline that does not allow for the 
ethanol 1.0 psi waiver does not qualify for the special regulatory 
treatment specified in paragraph (b)(1) of this section.
    (c) Exceptions. The RVP per-gallon standard in paragraph (a) of this 
section for the area in which the gasoline is located does not apply to 
that gasoline if the person(s) who produced, imported, sold, offered for 
sale, distributed, offered to distribute, supplied, offered for supply, 
dispensed, stored, transported, or introduced the gasoline into commerce 
can demonstrate one of the following:
    (1) The gasoline is designated as winter gasoline and was not sold, 
offered for sale, supplied, offered for supply, dispensed, or introduced 
into commerce for use during the summer season and was not delivered to 
any retail station or WPC during the summer season.
    (2) The gasoline is designated as summer gasoline for use in an area 
other

[[Page 539]]

than the area in which it is located and was not sold, offered for sale, 
supplied, offered for supply, dispensed, or introduced into commerce in 
the area in which the gasoline is located. In this case, the standard 
that applies to the gasoline is the standard applicable to the area for 
which the gasoline is designated.



Sec.  1090.220  RFG standards.

    The standards in this section apply to gasoline that is designated 
as RFG or RBOB or that is used in an RFG covered area. Gasoline that 
meets the requirements of this section is deemed to be in compliance 
with the requirements of 42 U.S.C. 7545(k).
    (a) Sulfur standards. RFG or RBOB must comply with the sulfur 
average standard in Sec.  1090.205(a) and the sulfur per-gallon 
standards in Sec.  1090.205(b) and (c).
    (b) Benzene standards. RFG or RBOB must comply with the benzene 
average standards in Sec.  1090.210(a) and (b).
    (c) RVP standard. Summer RFG or Summer RBOB must comply with the RFG 
RVP standard in Sec.  1090.215(a)(3).
    (d) Heavy metals standard. RFG or RBOB must not contain any heavy 
metals, including but not limited to lead or manganese. EPA may waive 
this prohibition for a heavy metal (other than lead) if EPA determines 
that addition of the heavy metal to the gasoline will not increase, on 
an aggregate mass or cancer-risk basis, toxic air pollutant emissions 
from motor vehicles.
    (e) Certified butane and certified pentane blending limitation. 
Certified butane and certified pentane must not be blended with Summer 
RFG or Summer RBOB under Sec.  1090.1320.



Sec.  1090.225  Anti-dumping standards.

    Gasoline that meets all applicable standards in this subpart is 
deemed to be in compliance with the anti-dumping requirements of 42 
U.S.C. 7545(k)(8).



Sec.  1090.230  Limitation on use of gasoline-ethanol blends.

    (a) No person may sell, introduce, cause or permit the sale or 
introduction of gasoline containing greater than 10 volume percent 
ethanol (e.g., E15) into any model year 2000 or older light-duty 
gasoline motor vehicle, any heavy-duty gasoline motor vehicle or engine, 
any highway or off-highway motorcycle, or any gasoline-powered nonroad 
engine, vehicle, or equipment.
    (b) Paragraph (a) of this section does not prohibit a person from 
producing, selling, introducing, or causing or allowing the sale or 
introduction of gasoline containing greater than 10 volume percent 
ethanol into any flex-fuel vehicle or flex-fuel engine.



Sec.  1090.250  Certified butane standards.

    Butane designated as certified butane under Sec.  1090.1000(e) for 
use under the butane blending provisions of Sec.  1090.1320(b) must meet 
the following per-gallon standards:
    (a) Butane content. Minimum 85 volume percent.
    (b) Benzene content. Maximum 0.03 volume percent.
    (c) Sulfur content. Maximum 10 ppm.
    (d) Chemical composition. Be composed solely of carbon, hydrogen, 
oxygen, nitrogen, and sulfur.



Sec.  1090.255  Certified pentane standards.

    Pentane designated as certified pentane under Sec.  1090.1000(f) for 
use under the pentane blending provisions of Sec.  1090.1320(b) must 
meet the following per-gallon standards:
    (a) Pentane content. Minimum 95 volume percent.
    (b) Benzene content. Maximum 0.03 volume percent.
    (c) Sulfur content. Maximum 10 ppm.
    (d) Chemical composition. Be composed solely of carbon, hydrogen, 
oxygen, nitrogen, and sulfur.



Sec.  1090.260  Gasoline deposit control standards.

    (a) Except as specified in subpart G of this part, all gasoline that 
is sold, offered for sale, dispensed, supplied, offered for supply, or 
transported to the ultimate consumer for use in motor vehicles or in any 
off-road engines, or that is transported to a gasoline retailer or WPC 
must be treated with a detergent that meets the requirements of 
paragraph (b) of this section at a rate at least as high as the 
detergent's LAC over the VAR period.
    (b) The LAC of the detergent must be determined by the gasoline 
detergent

[[Page 540]]

manufacturer using one of the following methods:
    (1) The detergent must comply with one of the deposit control 
testing methods specified in Sec.  1090.1395.
    (2) The detergent must have been certified prior to January 1, 2021, 
under the intake valve deposit control requirements of 40 CFR 80.165(b) 
for any of the detergent certification options under 40 CFR 80.163. Di-
tertiary butyl disulfide may have been used to meet the test fuel 
specifications under 40 CFR 80.164 associated with the intake valve 
deposit control requirements of 40 CFR 80.165(b). A party compliant with 
this paragraph (b)(2) is exempt from the port fuel injector deposit 
control requirements of 40 CFR 80.165(a).
    (3) A gasoline detergent manufacturer must produce detergents 
consistent with their detergent certifications for detergents certified 
prior to January 1, 2021, and with the specific composition information 
submitted as part of the registration of detergents under 40 CFR 
79.21(j) thereafter.



Sec.  1090.265  Gasoline additive standards.

    (a) Any gasoline additive that is added to, intended for adding to, 
used in, or offered for use in gasoline at any downstream location must 
meet all the following requirements:
    (1) Registration. The gasoline additive must be registered by a 
gasoline additive manufacturer under 40 CFR part 79.
    (2) Sulfur content. The gasoline additive must contribute less than 
or equal to 3 ppm on a per-gallon basis to the sulfur content of 
gasoline when used at the maximum recommended concentration.
    (3) Treatment rate. Except for oxygenates, the gasoline additive(s) 
must be used at a maximum treatment rate less than or equal to a 
combined total of 1.0 volume percent.
    (b) Any fuel additive blender that is not otherwise subject to any 
other requirement in this part and only blends a gasoline additive that 
meets the requirements of paragraph (a) of this section into gasoline is 
not subject to any requirement in this part solely due to this gasoline 
additive blending, except the downstream sulfur per-gallon standard in 
Sec.  1090.205(c), if all the following conditions are met:
    (1) The fuel additive blender blends gasoline additives into 
gasoline at a concentration less than or equal to a combined total of 
1.0 volume percent.
    (2) The fuel additive blender does not add any other blendstock into 
the gasoline except for oxygenates that meet the requirements in Sec.  
1090.270.
    (c) Any person who blends any fuel additive that does not meet the 
requirements of paragraphs (a) and (b) of this section is a gasoline 
manufacturer and must comply with all requirements applicable to a 
gasoline manufacturer under this part.
    (d) Any gasoline additive used or intended for use to comply with 
the gasoline deposit control requirement in Sec.  1090.260(a) must meet 
the gasoline deposit control standards under Sec.  1090.260(b).



Sec.  1090.270  Gasoline oxygenate standards.

    (a) All oxygenates designated for blending with gasoline or blended 
with gasoline must meet the following per-gallon standards:
    (1) Sulfur content. Maximum 10 ppm.
    (2) Chemical composition. Be composed solely of carbon, hydrogen, 
oxygen, nitrogen, and sulfur.
    (b) DFE designated for blending into gasoline or blended with 
gasoline must meet the following additional requirements:
    (1) Denaturant type. Only PCG, gasoline blendstocks, NGLs, or 
certified ethanol denaturant that meets the requirements in Sec.  
1090.275 may be used as denaturants.
    (2) Denaturant concentration. The concentration of all denaturants 
used in DFE must not exceed 3.0 volume percent.



Sec.  1090.275  Ethanol denaturant standards.

    (a) Standard for all ethanol denaturant. All ethanol denaturant, 
certified or uncertified, used to produce DFE must be composed solely of 
carbon, hydrogen, nitrogen, oxygen, and sulfur.
    (b) Standards for certified ethanol denaturant. In addition to the 
requirements of paragraph (a) of this section,

[[Page 541]]

certified ethanol denaturant must meet the following requirements:
    (1) Sulfur content per-gallon standard. Maximum 330 ppm. If the 
certified ethanol denaturant producer represents a batch of denaturant 
as having a maximum sulfur content less than 330 ppm on the PTD (for 
example, less than or equal to 120 ppm), then the actual sulfur content 
must be less than or equal to the stated value.
    (2) Denaturant type. Only PCG, gasoline blendstocks, or NGLs may be 
used to produce certified ethanol denaturant.



Sec.  1090.285  RFG covered areas.

    For purposes of this part, the RFG covered areas are as follows:
    (a) RFG covered areas specified in 42 U.S.C. 7545(k)(10)(D):

                   Table 1 to Paragraph (a)--RFG Covered Areas Under 42 U.S.C. 7545(k)(10)(D)
----------------------------------------------------------------------------------------------------------------
          Area designation                    State                    Counties             Independent cities
----------------------------------------------------------------------------------------------------------------
Los Angeles-Anaheim-Riverside......  California............  Los Angeles, Orange,
                                                              Ventura, San
                                                              Bernardino,\1\ Riverside
                                                              \2\.
San Diego County...................  California............  San Diego..................
Greater Connecticut................  Connecticut...........  Hartford, Middlesex, New
                                                              Haven, New London,
                                                              Tolland, Windham,
                                                              Fairfield (only the City
                                                              of Shelton), Litchfield
                                                              (all except the towns of
                                                              Bridgewater and New
                                                              Milford).
New York-Northern New Jersey-Long    Connecticut...........  Fairfield (all except the
 Island-Connecticut.                                          City of Shelton),
                                                              Litchfield (only the towns
                                                              of Bridgewater and New
                                                              Milford).
                                     New Jersey............  Bergen, Essex, Hudson,
                                                              Hunterdon, Middlesex,
                                                              Monmouth, Morris, Ocean,
                                                              Passaic, Somerset, Sussex,
                                                              Union.
                                     New York..............  Bronx, Kings, Nassau, New
                                                              York, Orange, Putnam,
                                                              Queens, Richmond,
                                                              Rockland, Suffolk,
                                                              Westchester.
Philadelphia-Wilmington-Trenton....  Delaware..............  Kent, New Castle...........
                                     Maryland..............  Cecil......................
                                     New Jersey............  Burlington, Camden,
                                                              Cumberland, Gloucester,
                                                              Mercer, Salem.
                                     Pennsylvania..........  Bucks, Chester, Delaware,
                                                              Montgomery, Philadelphia.
Chicago-Gary-Lake County...........  Illinois..............  Cook, Du Page, Kane, Lake,
                                                              McHenry, Will, Grundy
                                                              (only Aux Sable Township
                                                              and Goose Lake Township),
                                                              Kendall (only Oswego
                                                              Township).
                                     Indiana...............  Lake, Porter...............
Baltimore..........................  Maryland..............  Anne Arundel, Baltimore,     Baltimore.
                                                              Carroll, Harford, Howard.
Houston-Galveston-Brazoria.........  Texas.................  Brazoria, Chambers, Fort
                                                              Bend, Galveston, Harris,
                                                              Liberty, Montgomery,
                                                              Waller.
Milwaukee-Racine...................  Wisconsin.............  Kenosha, Milwaukee,
                                                              Ozaukee, Racine,
                                                              Washington, Waukesha.
----------------------------------------------------------------------------------------------------------------
\1\ That portion of San Bernardino County, CA that lies south of latitude 35 degrees, 10 minutes north and west
  of longitude 115 degrees, 45 minutes west.
\2\ That portion of Riverside County, CA that lies to the west of a line described as follows: Beginning at the
  northeast corner of Section 4, Township 2 South, Range 5 East, a point on the boundary line common to
  Riverside and San Bernardino Counties; then southerly along section lines to the centerline of the Colorado
  River Aqueduct; then southeasterly along the centerline of said Colorado River Aqueduct to the southerly line
  of Section 36, Township 3 South, Range 7 East; then easterly along the township line to the northeast corner
  of Section 6, Township 4 South, Range 9 East; then southerly along the easterly line of Section 6 to the
  southeast corner thereof; then easterly along section lines to the northeast corner of Section 10, Township 4
  South, Range 9 East; then southerly along section lines to the southeast corner of Section 15, Township 4
  South, Range 9 East; then easterly along the section lines to the northeast corner of Section 21, Township 4
  South, Range 10 East; then southerly along the easterly line of Section 21 to the southeast corner thereof;
  then easterly along the northerly line of Section 27 to the northeast corner thereof; then southerly along
  section lines to the southeast corner of Section 34, Township 4 South, Range 10 East; then easterly along the
  township line to the northeast corner of Section 2, Township 5 South, Range 10 East; then southerly along the
  easterly line of Section 2, to the southeast corner thereof; then easterly along the northerly line of Section
  12 to the northeast corner thereof; then southerly along the range line to the southwest corner of Section 18,
  Township 5 South, Range 11 East; then easterly along section lines to the northeast corner of Section 24,
  Township 5 South, Range 11 East; and then southerly along the range line to the southeast corner of Section
  36, Township 8 South, Range 11 East, a point on the boundary line common to Riverside and San Diego Counties.

    (b) RFG covered areas based on being reclassified as Severe ozone 
nonattainment areas under 42 U.S.C. 7511(b):

[[Page 542]]



              Table 2 to Paragraph (b)--Additional RFG Covered Areas Under 42 U.S.C. 7545(k)(10)(D)
----------------------------------------------------------------------------------------------------------------
          Area designation              State or district              Counties             Independent cities
----------------------------------------------------------------------------------------------------------------
Washington, DC-Maryland-Virginia...  District of Columbia..  Washington.................
                                     Maryland..............  Calvert, Charles,
                                                              Frederick, Montgomery,
                                                              Prince George's.
                                     Virginia..............  Arlington, Fairfax,          Alexandria, Fairfax,
                                                              Loudoun, Prince William,     Falls Church,
                                                              Stafford.                    Manassas, Manassas
                                                                                           Park.
Sacramento Metro...................  California............  Sacramento, Yolo, El Dorado
                                                              (except Lake Tahoe and its
                                                              drainage area), Placer,
                                                              \1\ Solano, \2\ Sutter \3\.
San Joaquin Valley.................  California............  Fresno, Kings, Madera,
                                                              Merced, San Joaquin,
                                                              Stanislaus, Tulare, Kern
                                                              \4\.
----------------------------------------------------------------------------------------------------------------
\1\ All portions of Placer County except that portion of the County within the drainage area naturally tributary
  to Lake Tahoe including said Lake, plus that area in the vicinity of the head of the Truckee River described
  as follows: Commencing at the point common to the aforementioned drainage area crestline and the line common
  to Townships 15 North and 16 North, Mount Diablo Base and Meridian (M.D.B.&M.), and following that line in a
  westerly direction to the northwest corner of Section 3, Township 15 North, Range 16 East, M.D.B.&M., thence
  south along the west line of Sections 3 and 10, Township 15 North, Range 16 East, M.D.B.&M., to the
  intersection with the said drainage area crestline, thence following the said drainage area boundary in a
  southeasterly, then northeasterly direction to and along the Lake Tahoe Dam, thence following the said
  drainage area crestline in a northeasterly, then northwesterly direction to the point of beginning.
\2\ That portion of Solano County that lies north and east of a line described as follows: Beginning at the
  intersection of the westerly boundary of Solano County and the \1/4\ section line running east and west
  through the center of Section 34; T. 6 N., R. 2 W., M.D.B.&M. thence east along said \1/4\ section line to
  the east boundary of Section 36, T. 6 N., R. 2 W.; thence south \1/2\ mile and east 2.0 miles, more or less,
  along the west and south boundary of Los Putos Rancho to the northwest corner of Section 4, T. 5 N., R. 1 W.;
  thence east along a line common to T. 5 N. and T. 6 N. to the northeast corner of Section 3, T. 5 N., R. 1 E.;
  thence south along section lines to the southeast corner of Section 10, T. 3 N., R. 1 E.; thence east along
  section lines to the south \1/4\ corner of Section 8, T. 3 N., R. 2 E.; thence east to the boundary between
  Solano and Sacramento Counties.
\3\ That portion of Sutter County south of a line connecting the northern border of Yolo Co. to the SW tip of
  Yuba Co. and continuing along the southern Yuba Co. border to Placer Co.
\4\ Boundary between the Kern County and San Joaquin Valley air districts that generally follows the ridge line
  of the Sierra Nevada and Tehachapi Mountain Ranges. That portion of Kern County that lies west and north of a
  line described as follows: Beginning at the Kern-Los Angeles County boundary and running north and east along
  the northwest boundary of the Rancho La Liebre Land Grant to the point of intersection with the range line
  common to Range 16 West and Range 17 West, San Bernardino Base and Meridian; north along the range line to the
  point of intersection with the Rancho El Tejon Land Grant boundary; then southeast, northeast, and northwest
  along the boundary of the Rancho El Tejon Grant to the northwest corner of Section 3, Township 11 North, Range
  17 West; then west 1.2 miles; then north to the Rancho El Tejon Land Grant boundary; then northwest along the
  Rancho El Tejon line to the southeast corner of Section 34, Township 32 South, Range 30 East, Mount Diablo
  Base and Meridian; then north to the northwest corner of Section 35, Township 31 South, Range 30 East; then
  northeast along the boundary of the Rancho El Tejon Land Grant to the southwest corner of Section 18, Township
  31 South, Range 31 East; then east to the southeast corner of Section 13, Township 31 South, Range 31 East;
  then north along the range line common to Range 31 East and Range 32 East, Mount Diablo Base and Meridian, to
  the northwest corner of Section 6, Township 29 South, Range 32 East; then east to the southwest corner of
  Section 31, Township 28 South, Range 32 East; then north along the range line common to Range 31 East and
  Range 32 East to the northwest corner of Section 6, Township 28 South, Range 32 East; then west to the
  southeast corner of Section 36, Township 27 South, Range 31 East; then north along the range line common to
  Range 31 East and Range 32 East to the Kern-Tulare County boundary.

    (c) RFG covered areas based on being classified ozone nonattainment 
areas at the time that the state requested to opt into RFG under 42 
U.S.C. 7545(k)(6)(A)(i):

                  Table 3 to Paragraph (c)--RFG Covered Areas Under 42 U.S.C. 7545(k)(6)(A)(i)
----------------------------------------------------------------------------------------------------------------
Area designation at the time of opt-
                 in                           State                    Counties             Independent cities
----------------------------------------------------------------------------------------------------------------
Sussex County......................  Delaware..............  Sussex.....................
St. Louis, Missouri-Illinois.......  Illinois..............  Jersey, Madison, Monroe,
                                                              St. Clair.
                                     Missouri..............  Franklin, Jefferson, St.     St. Louis.
                                                              Charles, St. Louis.
Kentucky portion of Louisville.....  Kentucky..............  Jefferson, Bullitt,\1\
                                                              Oldham \2\.
Kent and Queen Anne's Counties.....  Maryland..............  Kent, Queen Anne's.........
Statewide..........................  Massachusetts.........  All........................
Strafford, Merrimack, Hillsborough,  New Hampshire.........  Hillsborough, Merrimack,
 Rockingham Counties.                                         Rockingham, Strafford.
Atlantic City......................  New Jersey............  Atlantic, Cape May.........
New Jersey portion of Allentown-     New Jersey............  Warren.....................
 Bethlehem-Easton.
Dutchess County....................  New York..............  Dutchess...................

[[Page 543]]

 
Essex County.......................  New York..............  Essex (the portion of
                                                              Whiteface Mountain above
                                                              4,500 feet in elevation).
Statewide..........................  Rhode Island..........  All........................
Dallas-Fort Worth..................  Texas.................  Collin, Dallas, Denton,
                                                              Tarrant.
Norfolk-Virginia Beach, Newport      Virginia..............  James City, York...........  Chesapeake, Hampton,
 News (Hampton Roads).                                                                     Newport News,
                                                                                           Norfolk, Poquoson,
                                                                                           Portsmouth, Suffolk,
                                                                                           Virginia Beach,
                                                                                           Williamsburg.
Richmond...........................  Virginia..............  Charles City, Chesterfield,  Colonial Heights,
                                                              Hanover, Henrico.            Hopewell, Richmond.
----------------------------------------------------------------------------------------------------------------
\1\ In Bullitt County, KY, beginning at the intersection of Ky 1020 and the Jefferson-Bullitt County Line
  proceeding to the east along the county line to the intersection of county road 567 and the Jefferson-Bullitt
  County Line; proceeding south on county road 567 to the junction with Ky 1116 (also known as Zoneton Road);
  proceeding to the south on KY 1116 to the junction with Hebron Lane; proceeding to the south on Hebron Lane to
  Cedar Creek; proceeding south on Cedar Creek to the confluence of Floyds Fork turning southeast along a creek
  that meets Ky 44 at Stallings Cemetery; proceeding west along Ky 44 to the eastern most point in the
  Shepherdsville city limits; proceeding south along the Shepherdsville city limits to the Salt River and west
  to a point across the river from Mooney Lane; proceeding south along Mooney Lane to the junction of Ky 480;
  proceeding west on Ky 480 to the junction with Ky 2237; proceeding south on Ky 2237 to the junction with Ky 61
  and proceeding north on Ky 61 to the junction with Ky 1494; proceeding south on Ky 1494 to the junction with
  the perimeter of the Fort Knox Military Reservation; proceeding north along the military reservation perimeter
  to Castleman Branch Road; proceeding north on Castleman Branch Road to Ky 44; proceeding a very short distance
  west on Ky 44 to a junction with Ky 1020 and proceeding north on Ky 1020 to the beginning.
\2\ In Oldham County, KY, beginning at the intersection of the Oldham-Jefferson County Line with the southbound
  lane of Interstate 71; proceeding to the northeast along the southbound lane of Interstate 71 to the
  intersection of Ky 329 and the southbound lane of Interstate 71; proceeding to the northwest on Ky 329 to the
  intersection of Zaring Road on Ky 329; proceeding to the east-northeast on Zaring Road to the junction of
  Cedar Point Road and Zaring Road; proceeding to the north-northeast on Cedar Point Road to the junction of Ky
  393 and Cedar Point Road; proceeding to the south-southeast on Ky 393 to the junction of county road 746 (the
  road on the north side of Reformatory Lake and the Reformatory); proceeding to the east-northeast on county
  road 746 to the junction with Dawkins Lane (also known as Saddlers Mill Road) and county road 746; Proceeding
  to follow an electric power line east-northeast across from the junction of county road 746 and Dawkins Lane
  to the east-northeast across Ky 53 on to the La Grange Water Filtration Plant; proceeding on to the east-
  southeast along the power line then south across Fort Pickens Road to a power substation on Ky 146; proceeding
  along the power line south across Ky 146 and the Seaboard System Railroad track to adjoin the incorporated
  city limits of La Grange; then proceeding east then south along the La Grange city limits to a point abutting
  the north side of Ky 712; proceeding east-southeast on Ky 712 to the junction of Massie School Road and Ky
  712; proceeding to the south-southwest and then north-northwest on Massie School Road to the junction of Ky 53
  and Massie School Road; proceeding on Ky 53 to the north-northwest to the junction of Moody Lane and Ky 53;
  proceeding on Moody Lane to the south-southwest until meeting the city limits of La Grange; then briefly
  proceeding north following the La Grange city limits to the intersection of the northbound lane of Interstate
  71 and the La Grange city limits; proceeding southwest on the northbound lane of Interstate 71 until
  intersecting with the North Fork of Currys Fork; proceeding south-southwest beyond the confluence of Currys
  Fork to the south-southwest beyond the confluence of Floyds Fork continuing on to the Oldham-Jefferson County
  Line and proceeding northwest along the Oldham-Jefferson County Line to the beginning.

    (d) RFG covered areas located in the ozone transport region 
established by 42 U.S.C. 7511c(a) that a state has requested to opt into 
RFG under 42 U.S.C. 7545(k)(6)(B)(i)(I).

[85 FR 78469, Dec. 4, 2020, as amended at 87 FR 52484, Aug. 26, 2022]



Sec.  1090.290  Changes to RFG covered areas and procedures for opting out of RFG.

    (a) New RFG covered areas. (1) Effective 1 year after an area has 
been reclassified as a Severe ozone nonattainment area under 42 U.S.C. 
7511(b), such Severe area will become a covered area under the RFG 
program as required by 42 U.S.C. 7545(k)(10)(D). The geographic extent 
of each such covered area must be the nonattainment area boundaries as 
specified in 40 CFR part 81, subpart C, for the ozone NAAQS that was the 
subject of the reclassification.
    (2) Any classified ozone nonattainment area identified in 40 CFR 
part 81, subpart C, as Marginal, Moderate, Serious, or Severe may be 
included as a covered area upon the request of the governor of the state 
in which the area is located. EPA must do all the following:
    (i) Publish the governor's request in the Federal Register upon 
receipt.
    (ii) Establish an effective date that is not later than 1 year after 
the request is received unless EPA determines that there is insufficient 
capacity to supply RFG as required by 42 U.S.C. 7545(k)(6)(A)(ii).
    (3) Any ozone attainment area in the ozone transport region 
established by 42 U.S.C. 7511c(a) may be included as a

[[Page 544]]

covered area upon petition by the governor of the state in which the 
area is located as required by 42 U.S.C. 7545(k)(6)(B)(i). EPA must do 
all the following:
    (i) Publish the governor's request in the Federal Register as soon 
as practicable after it is received.
    (ii) Establish an effective date that is not later than 180 days 
after the request is received unless EPA determines that there is 
insufficient capacity to supply RFG as required by 42 U.S.C. 
7545(k)(6)(B)(iii).
    (b) Opting out of RFG. Any area that opted into RFG under 42 U.S.C. 
7545(k)(6)(A) or (B) and has not subsequently been reclassified as a 
Severe ozone nonattainment area may opt out of RFG using the opt-out 
procedure in paragraph (d) of this section.
    (c) Eligibility for opting out of RFG. The governor of the state in 
which a covered area under 42 U.S.C. 7545(k)(10)(D) is located may 
request that EPA remove the prohibition specified in 42 U.S.C. 
7545(k)(5) in such area by following the opt-out procedure specified in 
paragraph (d) of this section upon one of the following:
    (1) Redesignation to attainment for such area for the most stringent 
ozone NAAQS in effect at the time of redesignation.
    (2) Designation as an attainment area for the most stringent ozone 
NAAQS in effect at the time of the designation. The area must also be 
redesignated to attainment for the prior ozone NAAQS.
    (d) Procedure for opting out of RFG. EPA may approve a request from 
a state asking for either the removal of an RFG opt-in area (or portion 
of an RFG opt-in area), or the removal of a covered area (or portion of 
a covered area) under 42 U.S.C. 7545(k)(10)(D) that meets the criteria 
in paragraph (c) of this section, from the list of RFG covered areas in 
Sec.  1090.285 if it meets the requirements of paragraph (d)(1) of this 
section. If EPA approves such a request, an effective date will be set 
as specified in paragraph (d)(2) of this section. EPA will notify the 
state in writing of EPA's action on the request and the effective date 
of the removal when the request is approved.
    (1) An opt-out request must be signed by the governor of a state, or 
the governor's authorized representative, and must include all the 
following:
    (i) A geographic description of each RFG area (or portion of each 
RFG area) that is covered by the request.
    (ii) A description of all the means in which emissions reductions 
from RFG are relied upon in any approved SIP or any submitted SIP that 
has not yet been approved by EPA.
    (iii) For an RFG area covered by the request where emissions 
reductions from RFG are relied upon as specified in paragraph (d)(1)(ii) 
of this section, the request must include all the following information:
    (A) Identify whether the state is withdrawing any submitted SIP that 
has not yet been approved.
    (B)(1) Identify whether the state intends to submit a SIP revision 
to any approved SIP or any submitted SIP that has not yet been approved, 
which relies on emissions reductions from RFG, and describe any control 
measures that the state plans to submit to EPA for approval to replace 
the emissions reductions from RFG.
    (2) A description of the state's plans and schedule for adopting and 
submitting any revision to any approved SIP or any submitted SIP that 
has not yet been approved.
    (C) If the state is not withdrawing any submitted SIP that has not 
yet been approved and does not intend to submit a revision to any 
approved SIP or any submitted SIP that has not yet been approved, 
describe why no revision is necessary.
    (iv) The governor of a state, or the governor's authorized 
representative, must submit additional information upon request by EPA.
    (2)(i) Except as specified in paragraph (d)(2)(ii) of this section, 
EPA will set an effective date of the RFG opt-out as requested by the 
governor, or the governor's authorized representative, but no less than 
90 days from EPA's written notification to the state approving the RFG 
opt-out request.
    (ii) Where emissions reductions from RFG are included in an approved 
SIP or any submitted SIP that has not yet been approved, other than as a 
contingency measure consisting of a future

[[Page 545]]

opt-in to RFG, EPA will set an effective date of the RFG opt-out as 
requested by the governor, or the governor's authorized representative, 
but no less than 90 days from the effective date of EPA approval of the 
SIP revision that removes the emissions reductions from RFG, and, if 
necessary, provides emissions reductions to make up for those from RFG 
opt-out.
    (iii) Notwithstanding the provisions of paragraphs (d)(2)(i) and 
(ii) of this section, for an area in the ozone transport region that 
opted into RFG under 42 U.S.C. 7545(k)(6)(B), EPA will not set the 
effective date for removal of the area earlier than 4 years after the 
commencement date of opt-in.
    (4) EPA will publish a notice in the Federal Register announcing the 
approval of an RFG opt-out request and its effective date.
    (5) Upon the effective date for the removal of an RFG area (or 
portion of an RFG area) included in an approved request, such geographic 
area will no longer be considered an RFG covered area.
    (e) Revising list of RFG covered areas. EPA will periodically 
publish a final rule revising the list of RFG covered areas in Sec.  
1090.285.



Sec.  1090.295  Procedures for relaxing the federal 7.8 psi RVP standard.

    (a) EPA may approve a request from a state asking for relaxation of 
the federal 7.8 psi RVP standard for any area (or portion of an area) 
required to use such gasoline, if it meets the requirements of paragraph 
(b) of this section. If EPA approves such a request, an effective date 
will be set as specified in paragraph (c) of this section. EPA will 
notify the state in writing of EPA's action on the request and the 
effective date of the relaxation when the request is approved.
    (b) The request must be signed by the governor of the state, or the 
governor's authorized representative, and must include all the 
following:
    (1) A geographic description of each federal 7.8 psi gasoline area 
(or portion of such area) that is covered by the request.
    (2) A description of all the means in which emissions reduction from 
the federal 7.8 psi gasoline are relied upon in any approved SIP or in 
any submitted SIP that has not yet been approved by EPA.
    (3) For any federal 7.8 psi gasoline area covered by the request 
where emissions reductions from the federal 7.8 psi gasoline are relied 
upon as specified in paragraph (b)(2) of this section, the request must 
include the following information:
    (i) Identify whether the state is withdrawing any submitted SIP that 
has not yet been approved.
    (ii)(A) Identify whether the state intends to submit a SIP revision 
to any approved SIP or any submitted SIP that has not yet been approved, 
which relies on emissions reductions from federal 7.8 psi gasoline, and 
describe any control measures that the state plans to submit to EPA for 
approval to replace the emissions reductions from federal 7.8 psi 
gasoline.
    (B) A description of the state's plans and schedule for adopting and 
submitting any revision to any approved SIP or any submitted SIP that 
has not yet been approved.
    (iii) If the state is not withdrawing any submitted SIP that has not 
yet been approved and does not intend to submit a revision to any 
approved SIP or any submitted SIP that has not yet been approved, 
describe why no revision is necessary.
    (4) The governor of a state, or the governor's authorized 
representative, must submit additional information upon request by EPA.
    (c)(1) Except as specified in paragraph (c)(2) of this section, EPA 
will set an effective date of the relaxation of the federal 7.8 psi RVP 
standard as requested by the governor, or the governor's authorized 
representative, but no less than 90 days from EPA's written notification 
to the state approving the relaxation request.
    (2) Where emissions reductions from the federal 7.8 psi gasoline are 
included in an approved SIP or any submitted SIP that has not yet been 
approved, EPA will set an effective date of the relaxation of the 
federal 7.8 psi RVP standard as requested by the governor, or the 
governor's authorized representative, but no less than 90 days from the 
effective date of EPA approval of the

[[Page 546]]

SIP revision that removes the emissions reductions from the federal 7.8 
psi gasoline, and, if necessary, provides emissions reductions to make 
up for those from the federal 7.8 psi gasoline relaxation.
    (d) EPA will publish a notice in the Federal Register announcing the 
approval of any federal 7.8 psi gasoline relaxation request and its 
effective date.
    (e) Upon the effective date for the relaxation of the federal 7.8 
psi RVP standard in a subject area (or portion of a subject area) 
included in an approved request, such geographic area will no longer be 
considered a federal 7.8 psi gasoline area.
    (f) EPA will periodically publish a final rule revising the list of 
areas subject to the federal 7.8 psi RVP standard in Sec.  
1090.215(a)(2).



           Subpart D_Diesel Fuel and ECA Marine Fuel Standards



Sec.  1090.300  Overview and general requirements.

    (a) Diesel fuel is subject to the ULSD standards in Sec.  1090.305, 
except as follows:
    (1) Alternative sulfur standards apply for 500 ppm LM diesel fuel 
and ECA marine fuel as specified in Sec. Sec.  1090.320 and 1090.325, 
respectively.
    (2) Exemption provisions apply as specified in subpart G of this 
part.
    (b) Diesel fuel additives must meet the requirements in Sec.  
1090.310.
    (c) A diesel fuel manufacturer or diesel fuel additive manufacturer 
must demonstrate compliance with the standards in this subpart by 
measuring fuel parameters in accordance with subpart N of this part.
    (d) All the standards in this part apply to diesel fuel and diesel 
fuel additives on a per-gallon basis.
    (e)(1) No person may produce, import, sell, offer for sale, 
distribute, offer to distribute, supply, offer for supply, dispense, 
store, transport, or introduce into commerce any diesel fuel, ECA marine 
fuel, or diesel fuel additive that does not meet any standard set forth 
in this subpart.
    (2) Notwithstanding paragraph (e)(1) of this section, an importer 
may import diesel fuel that does not comply with the standards set forth 
in this subpart if all the following conditions are met:
    (i) The importer offloads the imported diesel fuel into one or more 
tanks that are physically located at the same import facility at which 
the imported diesel fuel first arrives in the United States or at a 
facility to which the imported diesel fuel is directly transported from 
the import facility at which the imported diesel fuel first arrived in 
the United States.
    (ii) The importer uses the imported diesel fuel to produce one or 
more new batches of diesel fuel.
    (iii) The importer certifies each new batch of diesel fuel under 
Sec.  1090.1000(c) and demonstrates that it complies with the standards 
in this subpart by measuring fuel parameters in accordance with subpart 
N of this part before custody or title to each new batch of diesel fuel 
is transferred.
    (f) No fuel or fuel additive manufacturer may introduce into 
commerce diesel fuel or diesel fuel additives that are not 
``substantially similar'' under 42 U.S.C. 7545(f)(1) or permitted under 
a waiver granted under 42 U.S.C. 7545(f)(4).
    (g) Distillate global marine fuel that does not qualify for an 
exemption under Sec.  1090.650 is subject to the standards, 
requirements, and prohibitions that apply for ULSD under this part.
    (h) No person may introduce used motor oil, or used motor oil 
blended with diesel fuel, into the fuel system of model year 2007 or 
later diesel motor vehicles or engines or model year 2011 or later 
nonroad diesel vehicles or engines (not including locomotive or marine 
diesel engines).



Sec.  1090.305  ULSD standards.

    (a) Overview. Except as specified in Sec.  1090.300(a), diesel fuel 
must meet the ULSD per-gallon standards of this section.
    (b) Sulfur standard. Maximum sulfur content of 15 ppm.
    (c) Cetane index or aromatic content. Diesel fuel must meet one of 
the following standards:
    (1) Minimum cetane index of 40.
    (2) Maximum aromatic content of 35 volume percent.

[[Page 547]]



Sec.  1090.310  Diesel fuel additives standards.

    (a) Except as specified in paragraph (b) and (c) of this section, 
diesel fuel additives blended into diesel fuel that is subject to the 
standards in Sec.  1090.305 must have a sulfur concentration less than 
or equal to 15 ppm on a per-gallon basis.
    (b) Diesel fuel additives do not have to comply with paragraph (a) 
of this section if all the following conditions are met:
    (1) The additive is added to diesel fuel in a quantity less than 1.0 
volume percent of the resultant mixture of additive and diesel fuel.
    (2) The PTD for the diesel fuel additive complies with the 
requirements in Sec.  1090.1120(b).
    (3) The additive is not commercially available as a retail product 
for ultimate consumers.
    (c) The provisions of this section do not apply to additives used 
with 500 ppm LM diesel fuel or ECA marine fuel.



Sec.  1090.315  Heating oil, kerosene, ECA marine fuel, 
and jet fuel provisions.

    Heating oil, kerosene, ECA marine fuel, and jet fuel must not be 
sold for use in motor vehicles or nonroad equipment and are not subject 
to the ULSD standards in Sec.  1090.305 unless also designated as ULSD 
under Sec.  1090.1015(a).



Sec.  1090.320  500 ppm LM diesel fuel standards.

    (a) Overview. 500 ppm LM diesel fuel produced or distributed by a 
transmix processor or pipeline operator under Sec.  1090.515 must meet 
the per-gallon standards of this section.
    (b) Sulfur standard. Maximum sulfur content of 500 ppm.
    (c) Cetane index or aromatic content. The standard for cetane index 
or aromatic content in Sec.  1090.305(c).



Sec.  1090.325  ECA marine fuel standards.

    (a) Overview. Except as specified in paragraph (c) of this section, 
ECA marine fuel must meet the per-gallon standards of this section.
    (b) Sulfur standard. Maximum sulfur content of 1,000 ppm.
    (c) Exceptions. The standards in paragraph (b) of this section do 
not apply to the following:
    (1) Residual fuel made available for use in a steamship or C3 marine 
vessel if the U.S. government exempts or excludes the vessel from MARPOL 
Annex VI fuel standards. Diesel fuel and other distillate fuel used in 
diesel engines operated on such vessels is subject to the standards in 
this section instead of the standards in Sec.  1090.305 or Sec.  
1090.320.
    (2) Distillate global marine fuel that is exempt under Sec.  
1090.650.

Subpart E [Reserved]



          Subpart F_Transmix and Pipeline Interface Provisions



Sec.  1090.500  Gasoline produced from blending transmix into PCG.

    (a) Applicability. (1) Except as specified in paragraph (a)(2) of 
this section, a transmix blender that blends transmix into PCG must 
comply with the requirements of this section.
    (2) Small volumes of fuel that are captured in pipeline sumps or 
trapped in pipeline pumps or valve manifolds and that are injected back 
into batches of gasoline or diesel fuel are exempt from the requirements 
in this section.
    (b) Requirements. (1) The distillation end-point of the resultant 
transmix-blended gasoline must not exceed 437 degrees Fahrenheit.
    (2) The resultant transmix-blended gasoline must meet the downstream 
sulfur per-gallon standard in Sec.  1090.205(c) and the applicable RVP 
standard in Sec.  1090.215.
    (3) The transmix blender must comply with the recordkeeping 
requirements in Sec.  1090.1255.
    (4) The transmix blender must maintain and follow a written quality 
assurance program that meets the requirements of paragraph (c) of this 
section.
    (5) In the event that the test result for any sample collected under 
the quality assurance program specified in paragraph (c) of this section 
indicates that the gasoline does not comply with any of the applicable 
standards in this part, the transmix blender must do all the following:
    (i) Immediately take steps to stop the sale of the gasoline that was 
sampled.
    (ii) Take reasonable steps to determine the cause of the 
noncompliance

[[Page 548]]

and prevent future instances of noncompliance.
    (iii) Notify EPA of the noncompliance.
    (iv) If the transmix was blended by a computer controlled in-line 
blending system, increase the rate of sampling and testing to a minimum 
frequency of once per week and a maximum frequency of once per day and 
continue the increased frequency of sampling and testing until the 
results of 10 consecutive samples and tests indicate that the gasoline 
complies with applicable standards, at which time the sampling and 
testing may be conducted at the original frequency.
    (c) Quality assurance program. (1) The quality assurance program 
must be designed to assure that the type and amount of transmix blended 
into PCG will not cause violations of the applicable fuel quality 
standards.
    (2) Except as specified in paragraph (c)(3) of this section, as a 
part of the quality assurance program, a transmix blender must collect 
samples of gasoline after blending transmix and test the samples to 
ensure the end-point temperature of the resultant transmix-blended 
gasoline does not exceed 437 degrees Fahrenheit, using one of the 
following sampling methods:
    (i) For transmix that is blended in a tank (including a tank on a 
barge), collect a representative sample of the resultant transmix-
blended gasoline following each occasion transmix is blended.
    (ii) For transmix that is blended by a computer controlled in-line 
blending system, the transmix blender must collect composite samples of 
the resultant transmix-blended gasoline at least twice each calendar 
month during which transmix is blended.
    (3) Any transmix blender may petition EPA for approval of a quality 
assurance program that does not include the minimum sampling and testing 
requirements of paragraph (c)(2) of this section. To seek approval for 
such an alternative quality assurance program, the transmix blender must 
submit a petition to EPA that includes all the following:
    (i) A detailed description of the quality assurance procedures to be 
carried out at each location where transmix is blended into PCG, 
including a description of how the transmix blender proposes to 
determine the ratio of transmix that can be blended with PCG without 
violating any of the applicable standards in this part, and a 
description of how the transmix blender proposes to determine that the 
gasoline produced by the transmix blending operation meets the 
applicable standards.
    (ii) A letter signed by the RCO or their delegate stating that the 
information contained in the submission is true to the best of their 
belief must accompany the petition.
    (iii) A transmix blender that petitions EPA to use an alternative 
quality assurance program must comply with any request by EPA for 
additional information or any other requirements that EPA includes as 
part of EPA's evaluation of the petition. However, the transmix blender 
may withdraw their petition or approved use of an alternative quality 
assurance program at any time, upon notice to EPA.



Sec.  1090.505  Gasoline produced from TGP.

    (a) General provisions. (1) A transmix processor or blending 
manufacturer that produces gasoline from TGP must meet the requirements 
of this section.
    (2) A transmix processor must not use any feedstock other than 
transmix to produce TGP.
    (3) A transmix processor or blending manufacturer may produce 
gasoline using only TGP, a combination of TGP and PCG, a combination of 
TGP and blendstock(s), or a combination TGP, PCG, and blendstock(s) 
under the provisions of this section. A transmix processor or blending 
manufacturer may also blend fuel additives into gasoline in accordance 
with Sec. Sec.  1090.260 and 1090.265.
    (b) Demonstration of compliance with sulfur per-gallon standard. (1) 
A transmix processor or blending manufacturer that produces gasoline 
with TGP must meet one of the following sulfur standards for each batch 
of gasoline they produce, as applicable:
    (i) Each batch of gasoline produced from only TGP or both TGP and 
PCG must comply with the downstream sulfur per-gallon standard in Sec.  
1090.205(c).

[[Page 549]]

    (ii) Each batch of gasoline produced from a combination of TGP and 
any blendstock must comply with the fuel manufacturing facility gate 
sulfur per-gallon standard in Sec.  1090.205(b).
    (2) A transmix processor or blending manufacturer that produces 
gasoline with TGP must demonstrate compliance with the applicable sulfur 
standard in paragraph (b)(1) of this section by measuring the sulfur 
content of each batch of gasoline they produce in accordance with 
subpart N of this part.
    (c) Demonstration of compliance with sulfur and benzene average 
standards. (1) A transmix processor or blending manufacturer that 
produces gasoline with TGP must exclude TGP and PCG used to produce 
gasoline under the provisions of this section from their compliance 
calculations to demonstrate compliance with the sulfur and benzene 
average standards in Sec. Sec.  1090.205(a) and 1090.210(a) and (b), 
respectively. A transmix processor or blending manufacturer that 
exclusively produces gasoline from only TGP or both TGP and PCG is 
deemed to be in compliance with the sulfur and benzene average standards 
in Sec. Sec.  1090.205(a) and 1090.210(a) and (b), respectively.
    (2) A transmix processor or blending manufacturer that produces 
gasoline with TGP must include all blendstocks other than TGP and PCG in 
their compliance calculations to demonstrate compliance with the sulfur 
and benzene average standards in Sec. Sec.  1090.205(a) and 1090.210(a) 
and (b), respectively.
    (3) A transmix processor or blending manufacturer that produces 
gasoline by adding blendstock to TGP must comply with Sec.  1090.1325.
    (d) Demonstration of compliance with RVP standard. A transmix 
processor or blending manufacturer that produces gasoline with TGP must 
demonstrate that each batch of gasoline they produce meets the 
applicable RVP standard in Sec.  1090.215 by measuring the RVP of each 
batch in accordance with subpart N of this part.
    (e) Distillation point determination. A transmix processor or 
blending manufacturer that produces gasoline with TGP must determine the 
following distillation parameters for each batch of gasoline they 
produce in accordance with subpart N of this part:
    (1) T10.
    (2) T50.
    (3) T90.
    (4) End-point.
    (5) Distillation residue.



Sec.  1090.510  Diesel and distillate fuel produced from TDP.

    (a) A transmix processor must not use any feedstock other than 
transmix to produce TDP.
    (b) A transmix processor must demonstrate that each batch of diesel 
fuel or distillate fuel produced from TDP meets the applicable standard 
in subpart D of this part and must comply with all other requirements 
applicable to a diesel fuel or distillate fuel manufacturer under this 
part.
    (c) A transmix processor that produces 500 ppm LM diesel fuel from 
TDP must also comply with the requirements in Sec.  1090.515.



Sec.  1090.515  500 ppm LM diesel fuel produced from TDP.

    (a) Applicability. A transmix processor that produces 500 ppm LM 
diesel fuel from TDP must comply with the requirements of this section 
and the standards for 500 ppm LM diesel fuel specified in Sec.  
1090.320.
    (b) Blending component limitation. A transmix processor may only use 
the following components to produce 500 ppm LM diesel fuel:
    (1) TDP.
    (2) ULSD.
    (3) Diesel fuel additives that comply with the requirements in Sec.  
1090.310.
    (c) Volume requirements. A party that handles 500 ppm LM diesel fuel 
must calculate the volume of 500 ppm LM diesel fuel received versus the 
volume delivered and used on a compliance period basis. An increase in 
the volume of 500 ppm LM diesel fuel delivered compared to the volume 
received must be due solely to one or more of the following:
    (1) Normal pipeline interface cutting practices under paragraph 
(e)(1) of this section.
    (2) The addition of ULSD to a retail outlet or WPC 500 ppm LM diesel 
fuel storage tank under paragraph (e)(2) of this section.
    (d) Use restrictions. 500 ppm LM diesel fuel may only be used in 
locomotive or

[[Page 550]]

marine engines that are not required to use ULSD under 40 CFR 1033.815 
or 40 CFR 1042.660, respectively. No person may use 500 ppm LM diesel 
fuel in locomotive or marine engines that are required to use ULSD, in 
any nonroad vehicle or engine, or in any motor vehicle engine.
    (e) Segregation requirement. A transmix processor or distributor 
must segregate 500 ppm LM diesel fuel from other fuels except as 
follows:
    (1) A pipeline operator may ship 500 ppm LM diesel fuel by pipeline 
provided that the 500 ppm LM diesel fuel does not come into physical 
contact in the pipeline with distillate fuels that have a sulfur content 
greater than 15 ppm. If 500 ppm LM diesel fuel is shipped by pipeline 
adjacent to ULSD, the pipeline operator must cut ULSD into the 500 ppm 
LM diesel fuel.
    (2) A WPC or retailer of 500 ppm LM diesel fuel may introduce ULSD 
into a storage tank that contains 500 ppm LM diesel fuel, provided that 
the other requirements of this section are satisfied. The resultant 
mixture must be designated as 500 ppm LM diesel fuel.
    (f) Party limit. No more than 4 separate parties may handle the 500 
ppm LM diesel fuel between the producer and the ultimate consumer.
    (g) Compliance plan. For each facility, a transmix processor that 
produces 500 ppm LM diesel fuel must obtain approval from EPA for a 
compliance plan at least 60 days prior to producing 500 ppm LM diesel 
fuel. The compliance plan must detail how the transmix processor intends 
to meet all the following requirements:
    (1) Demonstrate how the 500 ppm LM diesel fuel will be segregated by 
the producer through to the ultimate consumer from fuel having other 
designations in order to comply with the segregation requirement in 
paragraph (e) of this section.
    (2) Demonstrate that the end users of 500 ppm LM diesel fuel will 
also have access to ULSD for use in those engines that require ULSD.
    (3) Identify the parties that will handle the 500 ppm LM diesel fuel 
through to the ultimate consumer.
    (4) Identify all ultimate consumers that will be supplied with the 
500 ppm LM diesel fuel.
    (5) Demonstrate how misfueling of 500 ppm LM diesel fuel into 
vehicles, engines, or equipment that require the use of ULSD will be 
prevented.
    (6) Include an EPA registration number.



Sec.  1090.520  Handling practices for pipeline interface that is not transmix.

    (a) Subject to the limitations in paragraph (b) of this section, a 
pipeline operator may cut pipeline interface from two batches of 
gasoline subject to EPA standards that are shipped adjacent to each 
other by pipeline into either or both these batches of gasoline provided 
that this action does not cause or contribute to a violation of the 
standards in this part.
    (b) During the summer season, a pipeline operator must not cut 
pipeline interface from two batches of gasoline subject to different RVP 
standards that are shipped adjacent to each other by pipeline into the 
gasoline batch that is subject to the more stringent RVP standard. For 
example, during the summer season, a pipeline operator must not cut 
pipeline interface from a batch of RFG shipped adjacent to a batch of 
conventional gasoline into the batch of RFG.



         Subpart G_Exemptions, Hardships, and Special Provisions



Sec.  1090.600  General provisions.

    (a) Gasoline, diesel fuel, or IMO marine fuel subject to an 
exemption under this subpart is exempt from the standards and provisions 
of this part as specified in this subpart.
    (b) Fuel that does not meet all the requirements and conditions 
specified in this subpart for an exemption is subject to all applicable 
standards and requirements of this part.



Sec.  1090.605  National security and military use exemptions.

    (a) Fuel, fuel additive, and regulated blendstock that is produced, 
imported, sold, offered for sale, supplied, offered for supply, stored, 
dispensed, or transported for use in the following tactical military 
vehicles, engines, or equipment, including locomotive and marine 
engines, are exempt from the standards specified in this part:

[[Page 551]]

    (1) Tactical military vehicles, engines, or equipment, including 
locomotive or marine engines, that have an EPA national security 
exemption from the motor vehicle emission standards under 40 CFR parts 
85 or 86, or from the nonroad engine emission standards under 40 CFR 
parts 89, 92, 94, 1042, or 1068.
    (2) Tactical military vehicles, engines, or equipment, including 
locomotive or marine engines, that are not subject to a national 
security exemption from vehicle or engine emissions standards specified 
in paragraph (a)(1) of this section but, for national security purposes 
(e.g., for purposes of readiness, including training, for deployment 
overseas), need to be fueled on the same fuel as the vehicles, engines, 
or equipment that EPA has granted such a national security exemption.
    (b) The exempt fuel must meet all the following requirements:
    (1) It must be accompanied by PTDs that meet the requirements of 
subpart L of this part.
    (2) It must be segregated from non-exempt fuel at all points in the 
distribution system.
    (3) It must be dispensed from a fuel dispenser stand, fueling truck, 
or tank that is labeled with the appropriate designation of the fuel.
    (4) It must not be used in any vehicles, engines, or equipment, 
including locomotive and marine engines, other than those specified in 
paragraph (a) of this section.



Sec.  1090.610  Temporary research, development, and testing exemptions.

    (a) Requests for an exemption. (1) Any person may receive an 
exemption from the provisions of this part for fuel used for research, 
development, or testing (``R&D'') purposes by submitting the information 
specified in paragraph (c) of this section as specified in Sec.  
1090.10.
    (2) Any person that is performing emissions certification testing 
for a motor vehicle or motor vehicle engine under 42 U.S.C. 7525 or 
nonroad engine or nonroad vehicle under 42 U.S.C. 7546 is exempt from 
the provisions of this part for the fuel they are using for emissions 
certification testing if they have an exemption under 40 CFR parts 85 
and 86 to perform such testing.
    (b) Criteria for an R&D exemption. For an R&D exemption to be 
granted, the person requesting an exemption must meet all the following 
conditions:
    (1) Demonstrate that the exemption is for an appropriate R&D 
purpose.
    (2) Demonstrate that an exemption is necessary.
    (3) Design an R&D program that is reasonable in scope.
    (4) Have a degree of control consistent with the purpose of the 
program and EPA's monitoring requirements.
    (5) Meet the requirements specified in paragraphs (c) and (d) of 
this section.
    (c) Information required to be submitted. To aid in demonstrating 
each of the elements in paragraph (b) of this section, the person 
requesting an exemption must include, at a minimum, all the following 
information:
    (1) A concise statement of the purpose of the program demonstrating 
that the program has an appropriate R&D purpose.
    (2) An explanation of why the stated purpose of the program is 
unable to be achieved in a practicable manner without meeting the 
requirements of this part.
    (3) A demonstration of the reasonableness of the scope of the 
program, including all the following:
    (i) An estimate of the program's duration in time (including 
beginning and ending dates).
    (ii) An estimate of the maximum number of vehicles, engines, and 
equipment involved in the program, and the number of miles and engine 
hours that will be accumulated on each.
    (iii) The manner in which the information on vehicles, engines, or 
equipment used in the program will be recorded and made available to EPA 
upon request.
    (iv) The quantity of the fuel that does not comply with the 
requirements of this part, as applicable.
    (v) The specific applicable standard(s) of this part that would 
apply to the fuel expected to be used in the program.
    (4) With regard to control, a demonstration that the program affords 
EPA a monitoring capability, including all the following:

[[Page 552]]

    (i) A description of the technical and operational aspects of the 
program.
    (ii) The site(s) of the program (including facility name, street 
address, city, county, state, and ZIP code).
    (iii) The manner in which information on vehicles, engines, and 
equipment used in the program will be recorded and made available to EPA 
upon request.
    (iv) The manner in which information on the fuel used in the program 
(including quantity, fuel properties, name, address, telephone number, 
and contact person of the supplier, and the date received from the 
supplier) will be recorded and made available to EPA upon request.
    (v) The manner in which the party will ensure that the fuel will be 
segregated from fuel that meets the requirements of subparts C and D of 
this part, as applicable, and how fuel dispensers will be labeled to 
ensure that the fuel is not dispensed for use in motor vehicles or 
nonroad engines, vehicles, or equipment, including locomotive or marine 
engines, that are part of the R&D test program.
    (vi) The name, business address, telephone number, and title of the 
person(s) in the organization requesting an exemption from whom further 
information on the application may be obtained.
    (vii) The name, business address, telephone number, and title of the 
person(s) in the organization requesting an exemption who is responsible 
for recording and making available the information specified in this 
paragraph (c), and the location where such information will be 
maintained.
    (viii) Any other information requested by EPA to determine whether 
the test program satisfies the criteria of paragraph (b) of this 
section.
    (d) Additional requirements. (1) The PTDs associated with fuel must 
comply with the requirements of subpart L of this part.
    (2) The fuel must be designated as exempt fuel by the fuel 
manufacturer or supplier, as applicable.
    (3) The fuel must be kept segregated from non-exempt fuel at all 
points in the distribution system.
    (4) The fuel must not be sold, distributed, offered for sale or 
distribution, dispensed, supplied, offered for supply, transported to or 
from, or stored by a retail outlet or WPC facility, unless the WPC 
facility is associated with the R&D program that uses the fuel.
    (5) At the completion of the program, any emission control systems 
or elements of design that are damaged or rendered inoperative must be 
replaced on vehicles remaining in service or the responsible person will 
be liable for a violation of 42 U.S.C. 7522(a)(3), unless sufficient 
evidence is supplied that the emission controls or elements of design 
were not damaged.
    (e) Approval of exemption. EPA may grant an R&D exemption upon a 
demonstration that the requirements of this section have been met. The 
R&D exemption approval may include such terms and conditions as EPA 
determines necessary to monitor the exemption and to carry out the 
purposes of this part, including restoration of emission control 
systems.
    (1) The volume of fuel subject to the approval must not exceed the 
estimated amount in paragraph (c)(3)(iv) of this section, unless EPA 
grants an approval for a greater amount.
    (2) Any exemption granted under this section will expire at the 
completion of the test program or 1 year from the date of approval, 
whichever occurs first, and may only be extended upon re-application 
consistent with the requirements of this section.
    (3) If any information required by paragraph (c) of this section 
changes after approval of the exemption, the responsible person must 
notify EPA in writing immediately.
    (f) Notification of completion. Any person with an approved 
exemption under this section must notify EPA in writing within 30 days 
after completion of the R&D program.



Sec.  1090.615  Racing and aviation exemptions.

    (a) Fuel, fuel additive, and regulated blendstock that is used in 
aircraft, or racing vehicles or racing boats in sanctioned racing 
events, is exempt from the standards in subparts C and D of this part if 
all the requirements of this section are met.
    (b) The fuel, fuel additive, or regulated blendstock is identified 
on PTDs

[[Page 553]]

and on any fuel dispenser from which the fuel, fuel additive, or 
regulated blendstock is dispensed as restricted for use either in 
aircraft or in racing motor vehicles or racing boats that are used only 
in sanctioned racing events.
    (c) The fuel, fuel additive, or regulated blendstock is completely 
segregated from all other non-exempt fuel, fuel additive, or regulated 
blendstock throughout production, distribution, and sale to the ultimate 
consumer.
    (d) The fuel, fuel additive, or regulated blendstock is not made 
available for use as gasoline or diesel fuel subject to the standards in 
subparts C and D of this part, as applicable, or dispensed for use in 
motor vehicles or nonroad engines, vehicles, or equipment, including 
locomotive or marine engines, except for those used only in aircraft or 
in sanctioned racing events.



Sec.  1090.620  Exemptions for Guam, American Samoa, and the
Commonwealth of the Northern Mariana Islands.

    Fuel that is produced, imported, sold, offered for sale, supplied, 
offered for supply, stored, dispensed, or transported for use in the 
territories of Guam, American Samoa, or the Commonwealth of the Northern 
Mariana Islands, is exempt from the standards in subparts C and D of 
this part if all the following requirements are met:
    (a) The fuel is designated by the fuel manufacturer as gasoline, 
diesel fuel, or ECA marine fuel for use only in Guam, American Samoa, or 
the Commonwealth of the Northern Mariana Islands.
    (b) The fuel is used only in Guam, American Samoa, or the 
Commonwealth of the Northern Mariana Islands.
    (c) The fuel is accompanied by PTDs that meet the requirements of 
subpart L of this part.
    (d) The fuel is completely segregated from non-exempt fuel at all 
points from the point the fuel is designated as exempt fuel for use only 
in Guam, American Samoa, or the Commonwealth of the Northern Mariana 
Islands, while the exempt fuel is in the United States (including an ECA 
or an ECA associated area under 40 CFR 1043.20) but outside these 
territories.



Sec.  1090.625  Exemptions for California gasoline and diesel fuel.

    (a) California gasoline and diesel fuel exemption. California 
gasoline or diesel fuel that complies with all the requirements of this 
section is exempt from all other provisions of this part.
    (b) California gasoline and diesel fuel requirements. (1) Each batch 
of California gasoline or diesel fuel must be designated as such by its 
fuel manufacturer.
    (2) Designated California gasoline or diesel fuel must be segregated 
from fuel that is not California gasoline or diesel fuel at all points 
in the distribution system.
    (3) Except for as specified in paragraph (d) or (e) of this section, 
designated California gasoline or diesel fuel must ultimately be used 
only in the state of California.
    (4) Transferors and transferees of California gasoline or diesel 
fuel produced outside the state of California must meet the PTD 
requirements of subpart L of this part.
    (5) Each transferor and transferee of California gasoline or diesel 
fuel produced outside the state of California must maintain copies of 
the PTDs as specified in subpart M of this part.
    (6) California gasoline or diesel fuel must not be used in any part 
of the United States outside of the state of California unless the 
manufacturer or distributor recertifies or redesignates the batch of 
California gasoline or diesel fuel as specified in paragraph (d) or (e) 
of this section.
    (c) Use of California test methods and offsite sampling procedures. 
For any gasoline or diesel fuel that is not California gasoline or 
diesel fuel and that is either produced at a facility located in the 
state of California or is imported from outside the United States into 
the state of California, the manufacturer must do one of the following:
    (1) Comply with the sampling and testing provisions in subpart N of 
this part, as applicable.
    (2) Sample and test using methods approved in Title 13 of the 
California Code of Regulations.
    (3) Sample and test per a current and valid protocol agreement 
between the fuel manufacturer and the California Air Resources Board or 
by Executive

[[Page 554]]

Order from the California Air Resources Board. Such protocols or 
Executive Orders must be provided to EPA upon request.
    (d) California gasoline used outside of California. California 
gasoline may be used in any part of the United States outside of the 
state of California if the manufacturer or distributor of the California 
gasoline does one of the following:
    (1) Recertifies the California gasoline as gasoline under this part 
and includes the recertified gasoline in their average standard 
compliance calculations.
    (2) Designates the California gasoline as gasoline under this part 
without recertification and does all the following:
    (i) Demonstrates that the fuel meets all applicable requirements for 
California reformulated gasoline under Title 13 of the California Code 
of Regulations.
    (ii) Properly redesignates the fuel under Sec.  1090.1010(b)(2)(vi).
    (iii) Generates PTDs under subpart L of this part.
    (iv) Keeps records under subpart M of this part.
    (v) Does not include the California gasoline in their average 
standard compliance calculations.
    (e) California diesel used outside of California. California diesel 
fuel may be used in any part of the United States outside of the state 
of California and is deemed to meet the standards in subpart D of this 
part without recertification if the fuel designated as California diesel 
fuel meets all applicable requirements for diesel fuel under Title 13 of 
the California Code of Regulations and the manufacturer or distributor 
of the fuel does all the following:
    (1) The manufacturer or distributor properly redesignates the fuel 
under Sec.  1090.1015(b)(3)(iii).
    (2) The manufacturer or distributor generates PTDs under subpart L 
of this part.
    (3) The manufacturer or distributor keeps records under subpart M of 
this part.



Sec.  1090.630  Exemptions for Alaska, Hawaii, Puerto Rico,
and the U.S. Virgin Islands summer gasoline.

    Summer gasoline that is produced, imported, sold, offered for sale, 
supplied, offered for supply, stored, dispensed, or transported for use 
in the Alaska, Hawaii, Puerto Rico, or the U.S. Virgin Islands, is 
exempt from the RVP standards in Sec.  1090.215 if all the following 
requirements are met:
    (a) The summer gasoline is designated by the fuel manufacturer as 
summer gasoline for use only in Alaska, Hawaii, Puerto Rico, or the U.S. 
Virgin Islands.
    (b) The summer gasoline is used only in Alaska, Hawaii, Puerto Rico, 
or the U.S. Virgin Islands.
    (c) The summer gasoline is accompanied by PTDs that meet the 
requirements of subpart L of this part.
    (d) The summer gasoline is completely segregated from non-exempt 
gasoline at all points from the point the summer gasoline is designated 
as exempt fuel for use only in Alaska, Hawaii, Puerto Rico, or the U.S. 
Virgin Islands, while the exempt summer gasoline is in the United States 
but outside these states or territories.



Sec.  1090.635  Refinery extreme unforeseen hardship exemption.

    (a) In appropriate extreme, unusual, and unforeseen circumstances 
(e.g., circumstances like a natural disaster or refinery fire; not 
financial or supplier difficulties) that are clearly outside the control 
of the refiner and that could not have been avoided by the exercise of 
prudence, diligence, and due care, EPA may permit a refiner, for a brief 
period, to distribute fuel that is exempt from the standards in subparts 
C and D of this part if all the following requirements are met:
    (1) It is in the public interest to do so (e.g., distribution of the 
nonconforming fuel will not damage vehicles or engines and is necessary 
to meet projected temporary shortfalls in the supply of the fuel in a 
state or region of the United States for which the shortfall is unable 
to otherwise be compensated for).
    (2) The refiner exercised prudent planning and was not able to avoid 
the violation and has taken all reasonable

[[Page 555]]

steps to minimize the extent of the nonconformity.
    (3) The refiner shows how compliance will be achieved as 
expeditiously as possible.
    (4) The refiner agrees to make up any air quality detriment 
associated with the nonconforming fuel, where practicable.
    (5) The refiner pays to the U.S. Treasury an amount equal to the 
economic benefit of the nonconformity minus the amount expended under 
paragraph (a)(4) of this section, in making up the air quality 
detriment.
    (b) Hardship applications under this section must be submitted to 
EPA as specified in Sec.  1090.10 and must contain a letter signed by 
the RCO, or their delegate, stating that the information contained in 
the application is true and accurate to the best of their knowledge.



Sec.  1090.640  Exemptions from the gasoline deposit control requirements.

    (a) Gasoline that is used to produce E85 is exempt from the gasoline 
deposit control requirements in Sec.  1090.260.
    (b) Any person that uses the exemption in paragraph (a) of this 
section must keep records to demonstrate that such exempt gasoline was 
used to produce E85 and was not distributed from a terminal for use as 
gasoline.



Sec.  1090.645  Exemption for exports of fuels, fuel additives, 
and regulated blendstocks.

    (a) Fuel, fuel additive, and regulated blendstock that is exported 
for sale outside of the United States is exempt from the standards in 
subparts C and D of this part if all the following requirements are met:
    (1) The fuel, fuel additive, or regulated blendstock is designated 
for export by the fuel manufacturer, fuel additive manufacturer, or 
regulated blendstock producer.
    (2) The fuel, fuel additive, or regulated blendstock designated for 
export is accompanied by PTDs that meet the requirements of subpart L of 
this part.
    (3) The fuel manufacturer, fuel additive manufacturer, or regulated 
blendstock producer keeps records that demonstrate that the fuel, fuel 
additive, or regulated blendstock was ultimately exported from the 
United States.
    (4) The fuel, fuel additive, or regulated blendstock is completely 
segregated from non-exempt fuels, fuel additives, and regulated 
blendstocks from the point the fuel, fuel additive, or regulated 
blendstock is designated for export to the point where it is ultimately 
exported from the United States.
    (5) Fuel, fuel additive, or regulated blendstock certified and 
designated for export may be certified for use in the United States if 
all the applicable requirements of this part are met.
    (b) Any fuel dispensed from a retail outlet within the geographic 
boundaries of the United States is not exempt under this section.



Sec.  1090.650  Distillate global marine fuel exemption.

    (a) The standards of subpart D of this part do not apply to 
distillate global marine fuel that is produced, imported, sold, offered 
for sale, supplied, offered for supply, stored, dispensed, or 
transported for use in steamships or Category 3 marine vessels when 
operating outside of ECA boundaries.
    (b) Exempt distillate global marine fuel under paragraph (a) of this 
section must meet all the following requirements:
    (1) The fuel must not exceed 0.50 weight percent sulfur (5,000 ppm).
    (2) The fuel must be accompanied by PTDs as specified in Sec.  
1090.1115.
    (3) The fuel must be designated as specified in Sec.  1090.1015.
    (4) The fuel must be segregated from non-exempt fuel at all points 
in the distribution system.
    (5) The fuel must not be used in vehicles, engines, or equipment 
other than those referred to in paragraph (a) of this section.
    (c)(1) Fuel that does not meet the requirements specified in 
paragraph (b) of this section is subject to the standards, requirements, 
and prohibitions that apply for ULSD under this part.
    (2) Any person who produces, imports, sells, offers for sale, 
supplies, offers for supply, stores, dispenses, or transports distillate 
global marine fuel without meeting the applicable recordkeeping 
requirements in subpart M of

[[Page 556]]

this part must not claim the fuel is exempt from the standards, 
requirements, and prohibitions that apply for ULSD under this part.



          Subpart H_Averaging, Banking, and Trading Provisions



Sec.  1090.700  Compliance with average standards.

    (a) Compliance with the sulfur average standard. For each of their 
facilities, a gasoline manufacturer must demonstrate compliance with the 
sulfur average standard in Sec.  1090.205(a) by using the equations in 
paragraphs (a)(1) and (2) of this section.
    (1) Compliance sulfur value calculation. (i) The compliance sulfur 
value is determined as follows:
CSVy = Stot,y + Ds,(y-1) + DS_Oxy_Total 
- CS

Where:

CSVy = Compliance sulfur value for compliance period y, in 
          ppm-gallons.
Stot,y = The total amount of sulfur produced in compliance 
          period y, per paragraph (a)(1)(ii) of this section, in ppm-
          gallons.
Ds,(y-1) = Sulfur deficit from the previous compliance 
          period, per Sec.  1090.715(a)(1), in ppm-gallons.
DS_Oxy_Total = The total sulfur deficit from BOB 
          recertification, per Sec.  1090.740(b)(2), in ppm-gallons.
CS = Sulfur credits used by the gasoline manufacturer, per 
          Sec.  1090.720, in ppm-gallons.

    (ii) The total amount of sulfur produced is determined as follows:
    [GRAPHIC] [TIFF OMITTED] TR04DE20.000
    
Where:
Vi = The volume of gasoline produced or imported in batch i, 
          in gallons.
Si = The sulfur content of batch i, in ppm.
n = The number of batches of gasoline produced or imported during the 
          compliance period.
i = Individual batch of gasoline produced or imported during the 
          compliance period.

    If the calculation of Stot,y results in a negative 
number, replace it with zero.
    (2) Sulfur compliance calculation. (i) Compliance with the sulfur 
average standard in Sec.  1090.205(a) is achieved if the following 
equation is true:
[GRAPHIC] [TIFF OMITTED] TR04DE20.001

    (ii) Compliance with the sulfur average standard in Sec.  
1090.205(a) is not achieved if a deficit is incurred two or more 
consecutive years. A gasoline manufacturer incurs a deficit under Sec.  
1090.715 if the following equation is true:
[GRAPHIC] [TIFF OMITTED] TR04DE20.002

    (b) Compliance with the benzene average standards. For each of their 
facilities, a gasoline manufacturer must demonstrate compliance with the 
benzene average standard in Sec.  1090.210(a) by using the equations in 
paragraphs (b)(1) and (2) of this section and with the maximum benzene 
average standard in Sec.  1090.210(b) by using the equations in 
paragraphs (b)(3) and (4) of this section.

[[Page 557]]

    (1) Compliance benzene value calculation. (i) The compliance benzene 
value is determined as follows:
CBVy = Btot,y + DBz,(y-1) + 
DBz_Oxy_Total - CBz

Where:

    CBVy = Compliance benzene value for compliance period y, 
in benzene gallons.
    Btot,y = The total amount of benzene produced in 
compliance period y, per paragraph (b)(1)(ii) of this section, in 
benzene gallons.
    DBz,(y-1) = Benzene deficit from the previous compliance 
period, per Sec.  1090.715(a)(2), in benzene gallons.
    DBz_Oxy_Total = The total benzene deficit from BOB 
recertification, per Sec.  1090.740(b)(4), in benzene gallons.
    CBz = Benzene credits used by the gasoline manufacturer, 
per Sec.  1090.720, in benzene gallons.

    (ii) The total amount of benzene produced is determined as follows:
    [GRAPHIC] [TIFF OMITTED] TR04DE20.003
    
Vi = The volume of gasoline produced or imported in batch i, 
          in gallons.
Bi = The benzene content of batch i, in volume percent.
n = The number of batches of gasoline produced or imported during the 
          compliance period.
i = Individual batch of gasoline produced or imported during the 
          compliance period.

    If the calculation of Btot,y results in a negative 
number, replace it with zero.
    (2) Benzene average compliance calculation. (i) Compliance with the 
benzene average standard in Sec.  1090.210(a) is achieved if the 
following equation is true:
[GRAPHIC] [TIFF OMITTED] TR04DE20.004

    (ii) Compliance with the benzene average standard in Sec.  
1090.210(a) is not achieved if a deficit is incurred two or more 
consecutive years. A gasoline manufacturer incurs a deficit under Sec.  
1090.715 if the following equation is true:
[GRAPHIC] [TIFF OMITTED] TR04DE20.005

    (3) Average benzene concentration calculation. The average benzene 
concentration is determined as follows:
[GRAPHIC] [TIFF OMITTED] TR04DE20.006

Where:

Ba,y = Average benzene concentration for compliance period y, 
          in volume percent benzene.

    (4) Maximum benzene average compliance calculation. Compliance with 
the maximum benzene average standard in Sec.  1090.210(b) is achieved 
for compliance period y if the following equation is true:

Ba,y <= 1.30 vol%

    (5) Rounding and reporting benzene values. (i) The total amount of 
benzene produced, as calculated in paragraph

[[Page 558]]

(b)(1)(ii) of this section, must be rounded to the nearest whole benzene 
gallon in accordance with Sec.  1090.50.
    (ii) The average benzene concentration, as calculated in paragraph 
(b)(3) of this section, must be rounded and reported to two decimal 
places in accordance with Sec.  1090.50.
    (c) Accounting for oxygenate added at a downstream location. A 
gasoline manufacturer that complies with the requirements in Sec.  
1090.710 may include the volume of oxygenate added at a downstream 
location and the effects of such blending on sulfur content and benzene 
content in compliance calculations under this subpart.
    (d) Inclusions. A gasoline manufacturer must include the following 
products that they produced or imported during the compliance period in 
their compliance calculations:
    (1) CG.
    (2) RFG.
    (3) BOB.
    (4) Added gasoline volume resulting from the production of gasoline 
from PCG as follows:
    (i) For PCG by subtraction under Sec.  1090.1320(a)(1), include the 
PCG batch as a batch with a negative volume, positive sulfur content, 
and positive benzene content and include the new batch of gasoline as a 
batch with a positive volume, positive sulfur content, and positive 
benzene content in compliance calculations under this section. Any 
negative compliance sulfur value or compliance benzene value must be 
reported as zero and not as a negative result.
    (ii) For PCG by addition under Sec.  1090.1320(a)(2), include only 
the blendstock added to make the new batch of gasoline as a batch with a 
positive volume, positive sulfur content, and positive benzene content 
in compliance calculations under this section. Do not include any test 
results or volumes for the PCG or new batch of gasoline in these 
calculations.
    (5)(i) Inclusion of a particular batch of gasoline for compliance 
calculations for a compliance period is based on the date the batch is 
produced, not shipped. For example, a batch produced on December 30, 
2021, but shipped on January 2, 2022, would be included in the 
compliance calculations for the 2021 compliance period. The volume 
included in the 2021 compliance period for that batch would be the 
entire batch volume, even though the shipment of all or some of the 
batch did not occur until 2022.
    (ii) For PCG by subtraction under Sec.  1090.1320(a)(1), include PCG 
in the compliance period in which it was blended with blendstock. This 
may necessitate reporting a portion of the volume of PCG received in one 
compliance period as a separate PCG batch in the following compliance 
period.
    (e) Exclusions. A gasoline manufacturer must exclude the following 
products from their compliance calculations:
    (1) Gasoline that was not produced by the gasoline manufacturer.
    (2) Blendstock, unless the blendstock is added to PCG or TGP under 
Sec.  1090.1320 or Sec.  1090.1325, respectively.
    (3) PCG, except as specified in paragraph (d)(4)(i) of this section.
    (4) Certified butane and certified pentane blended under Sec.  
1090.1320(b).
    (5) TGP.
    (6) GTAB that meets the requirements in Sec.  1090.1615(a).
    (7) Gasoline imported by truck or rail using the provisions of Sec.  
1090.1610 to meet the alternative per-gallon standards of Sec. Sec.  
1090.205(d) and 1090.210(c).
    (8) Gasoline exempt under subpart G of this part from the average 
standards of subpart C of this part (e.g., California gasoline, racing 
fuel, etc.).



Sec.  1090.705  Facility level compliance.

    (a) Except as specified in paragraph (b) of this section, a gasoline 
manufacturer must comply with average standards at the individual 
facility level.
    (b) A gasoline importer must comply with average standards at the 
company level, except that aggregation of all import facilities within a 
PADD as a single facility is required for compliance with the maximum 
benzene average standard in Sec.  1090.210(b).



Sec.  1090.710  Downstream oxygenate accounting.

    The requirements of this section apply to BOB for which a gasoline 
manufacturer accounts for the effects of the oxygenate blending that 
occurs downstream of the fuel manufacturing

[[Page 559]]

facility in the gasoline manufacturer's average standard compliance 
calculations under this subpart. This section also includes requirements 
for oxygenate blenders to ensure that oxygenate is added in accordance 
with the blending instructions specified by the gasoline manufacturer in 
order to ensure fuel quality standards are met.
    (a) Provisions for gasoline manufacturers. In order to account for 
the effects of oxygenate blending downstream, a gasoline manufacturer 
must meet all the following requirements:
    (1) Produce or import BOB such that the gasoline continues to meet 
the applicable gasoline standards in subpart C of this part after the 
addition of the specified type and amount of oxygenate.
    (2) For each batch of BOB produced or imported, create a hand blend 
in accordance with Sec.  1090.1340 and determine the properties of the 
hand blend using the methods specified in subpart N of this part.
    (3) Participate in the NSTOP specified in Sec.  1090.1450 or have an 
approved in-line blending waiver under Sec.  1090.1315.
    (4) Transfer ownership of the BOB only to an oxygenate blender that 
is registered with EPA under subpart I of this part or to an 
intermediate owner with the restriction that it only be transferred to a 
registered oxygenate blender.
    (5) Specify on the PTD for the BOB each oxygenate type and amount 
(or range of amounts) for which the hand blend was certified for 
compliance under Sec.  1090.1340.
    (6) Participate in the NFSP under subpart O of this part.
    (b) Requirements for oxygenate blenders. An oxygenate blender must 
add oxygenate of each type and amount (or within the range of amounts) 
as specified on the PTD for all BOB received, except as specified in 
paragraph (c)(2) of this section.
    (c) Limitations. (1) Only the gasoline manufacturer that first 
certifies the BOB may account for the downstream addition of oxygenate 
under this section. On any occasion where any person downstream of the 
fuel manufacturing facility gate of the gasoline manufacturer that 
produced or imported gasoline or BOB adds oxygenate to such product, the 
person must not include the volume, sulfur content, and benzene content 
of the oxygenate in any compliance calculations for demonstrating 
compliance with the average standards specified in subpart C of this 
part or for credit generation under this subpart. All applicable per-
gallon standards specified in subpart C of this part continue to apply.
    (2) A person downstream of the fuel manufacturing facility gate may 
recertify BOB for use as gasoline without the addition of the specified 
type and amount of oxygenate if the provisions of Sec.  1090.740 are 
met. A person who recertifies BOB for use as gasoline without the 
addition of the specified type and amount of oxygenate is a gasoline 
manufacturer and must meet all applicable requirements for a gasoline 
manufacturer specified in this part.



Sec.  1090.715  Deficit carryforward.

    (a) A gasoline manufacturer incurs a compliance deficit if they 
exceed the average standard specified in subpart C of this part for a 
given compliance period. The deficit incurred must be determined as 
specified in paragraph (a)(1) of this section for sulfur and paragraph 
(a)(2) of this section for benzene.
    (1) The sulfur deficit incurred is determined as follows:
    [GRAPHIC] [TIFF OMITTED] TR04DE20.007
    
Where:

DS,y = Sulfur deficit incurred for compliance period y, in 
          ppm-gallons.
CSVy = Compliance sulfur value for compliance period y, per 
          Sec.  1090.700(a)(1), in ppm-gallons.

[[Page 560]]

Vi = The volume of gasoline produced or imported in batch i, 
          in gallons.
n = The number of batches of gasoline produced or imported during the 
          compliance period.
i = Individual batch of gasoline produced or imported during the 
          compliance period.

    (2) The benzene deficit incurred is determined as follows:
    [GRAPHIC] [TIFF OMITTED] TR04DE20.008
    
Where:

DBz,y = Benzene deficit incurred for compliance period y, in 
          benzene gallons.
CBVy = Compliance benzene value for compliance period y, per 
          Sec.  1090.700(b)(1)(i), in ppm-gallons.
Vi = The volume of gasoline produced or imported in batch i, 
          in gallons.
n = The number of batches of gasoline produced or imported during the 
          compliance period.
i = Individual batch of gasoline produced or imported during the 
          compliance period.

    (b) A gasoline manufacturer must use all sulfur or benzene credits 
previously generated or obtained at any of their facilities to achieve 
compliance with an average standard specified in subpart C of this part 
before carrying forward a sulfur or benzene deficit at any of their 
facilities.
    (c) A gasoline manufacturer that incurs a deficit under this section 
must satisfy that deficit and demonstrate compliance with the annual 
average standards during the next compliance period regardless of 
whether the gasoline manufacturer produces gasoline during next 
compliance period.



Sec.  1090.720  Credit use.

    (a) General credit use provisions. Only a gasoline manufacturer may 
generate, use, transfer, or own credits generated under this subpart, as 
specified in Sec.  1090.725(a)(1). Credits may be used by a gasoline 
manufacturer to comply with the average standards specified in subpart C 
of this part. A gasoline manufacturer may also bank credits for future 
use, transfer credits to another facility within the company (i.e., 
intracompany trading), or transfer credits to another gasoline 
manufacturer, if all applicable requirements of this subpart are met.
    (b) Credit life. Credits are valid for use for 5 years after the 
compliance period for which they are generated.
    (c) Limitations on credit use. (1) Credits that have expired must 
not be used for demonstrating compliance with the average standards 
specified in subpart C of this part or be used to replace invalid 
credits under Sec.  1090.735.
    (2) A gasoline manufacturer possessing credits must use all credits 
prior to incurring a compliance deficit under Sec.  1090.715.
    (3) Credits must not be used to meet per-gallon standards.
    (4) Credits must not be used to meet the maximum benzene average 
standard in Sec.  1090.210(b).
    (5) Credits may only be used if the gasoline manufacturer owns them 
at the time of use.
    (d) Credit reporting. A gasoline manufacturer that generates, 
transacts, or uses credits under this subpart must report to EPA as 
specified in Sec.  1090.905 using forms and procedures specified by EPA.
    (e) Part 80 credit use. Valid credits generated under 40 CFR 80.1615 
and 80.1290 may be used by a gasoline manufacturer to comply with the 
average standards in subpart C of this part, subject to the provisions 
of this subpart.



Sec.  1090.725  Credit generation.

    (a) Parties that may generate credits. (1) No person other than a 
gasoline manufacturer may generate credits for use towards an average 
standard specified in subpart C of this part.
    (2) No credits may be generated for gasoline produced by any of the 
following activities:
    (i) Transmix processing.
    (ii) Transmix blending.
    (iii) Oxygenate blending.

[[Page 561]]

    (iv) Certified butane blending.
    (v) Certified pentane blending.
    (vi) Importation of gasoline by rail and truck using the alternative 
sampling and testing requirements in Sec.  1090.1610.
    (3) No sulfur credits may be generated at a facility if that 
facility used sulfur credits in that same compliance period.
    (4) No benzene credits may be generated at a facility if that 
facility used benzene credits in that same compliance period.
    (b) Credit year. Credits generated under this section must be 
identified by the compliance period of generation. For example, credits 
generated on gasoline produced in 2021 must be identified as 2021 
credits.
    (c) Sulfur credit generation. (1) The number of sulfur credits 
generated is determined as follows:
[GRAPHIC] [TIFF OMITTED] TR04DE20.009

Where:

CS,y = Sulfur credits generated for compliance period y, in 
          ppm-gallons.
Vi = The volume of gasoline produced or imported in batch i, 
          in gallons.
n = The number of batches of gasoline produced or imported during the 
          compliance period.
i = Individual batch of gasoline produced or imported during the 
          compliance period.
CSVy = Compliance sulfur value for compliance period y, per 
          Sec.  1090.700(a)(1), in ppm-gallons.

    (2) The value of CS,y must be positive to generate 
credits.
    (3) Sulfur credits calculated under paragraph (c)(1) of this section 
must be expressed to the nearest ppm-gallon. Fractional values must be 
rounded in accordance with Sec.  1090.50.
    (d) Benzene credit generation. (1) The number of benzene credits 
generated is determined as follows:
[GRAPHIC] [TIFF OMITTED] TR04DE20.010

Where:

CBz,y = Benzene credits generated for compliance period y, in 
          benzene gallons.
Vi = The volume of gasoline produced or imported in batch i, 
          in gallons.
n = The number of batches of gasoline produced or imported during the 
          compliance period.
i = Individual batch of gasoline produced or imported during the 
          compliance period.
CBVy = Compliance benzene value for compliance period y, per 
          Sec.  1090.700(b)(1)(i), in benzene gallons.

    (2) The value of CBz,y must be positive to generate 
credits.
    (3) Benzene credits calculated under paragraph (d)(1) of this 
section must be expressed to the nearest benzene gallon. Fractional 
values must be rounded in accordance with Sec.  1090.50.
    (e) Credit generation limitation. A gasoline manufacturer may only 
generate credits after they have finished producing or importing 
gasoline for the compliance period.
    (f) Credit generation reporting. A gasoline manufacturer that 
generates credits under this section must report to EPA all credit 
generation information as specified in Sec.  1090.905 using forms and 
procedures specified by EPA.



Sec.  1090.730  Credit transfers.

    A gasoline manufacturer may only transfer or obtain credits from 
another gasoline manufacturer to meet an average standard specified in 
subpart C of this part if all applicable requirements of this section 
are met.

[[Page 562]]

    (a) The credits are generated as specified in Sec.  1090.725 and 
reported as specified in Sec.  1090.905.
    (b) The credits are used for compliance in accordance with the 
limitations on credit use specified in Sec.  1090.720(c).
    (c) Any credit transfer must take place no later than the deadline 
specified in Sec.  1090.900(c) following the compliance period in which 
the credits are obtained.
    (d) The credit has not been transferred between EPA registered 
companies more than twice. The first transfer by the gasoline 
manufacturer that generated the credit (``transferor'') must only be 
made to a gasoline manufacturer that intends to use the credit 
(``transferee''). If the transferee is unable to use the credit, it may 
make the second, and final, transfer only to a gasoline manufacturer 
that intends to use the credit. Intracompany credit transfers are 
unlimited.
    (e) The transferor must apply any credits necessary to meet the 
transferor's applicable average standard before transferring credits to 
any other gasoline manufacturer.
    (f) No person may transfer credits if the transfer would cause them 
to incur a deficit.
    (g) Unless the transferor and transferee are the same party (i.e., 
intracompany transfers), the transferor must supply to the transferee 
records as specified in Sec.  1090.1210(g) indicating the year(s) the 
credits were generated, the identity of the gasoline manufacturer that 
generated the credits, and the identity of the transferring party.
    (h) The transferor and the transferee must report to EPA all 
information regarding the transaction as specified in Sec.  1090.905 
using forms and procedures specified by EPA.



Sec.  1090.735  Invalid credits and remedial actions.

    For credits that have been calculated or generated improperly, or 
are otherwise determined to be invalid, all the following provisions 
apply:
    (a) Invalid credits must not be used to achieve compliance with an 
average standard under this part, regardless of the good faith belief 
that the credits were validly generated.
    (b) Any validly generated credits existing in the transferring 
gasoline manufacturer's credit balance after correcting the credit 
balance, and after the transferor applies credits as needed to meet the 
average standard at the end of the compliance period, must first be 
applied to correct the invalid transfers before the transferring 
gasoline manufacturer trades or banks the credits.
    (c) The gasoline manufacturer that used the credits, and any 
transferor of the credits, must adjust their credit records, reports, 
and average standard compliance calculations as necessary to reflect the 
use of valid credits only. Updates to any reports must be done in 
accordance with subpart J of this part using forms and procedures 
specified by EPA.



Sec.  1090.740  Downstream BOB recertification.

    (a)(1) A gasoline manufacturer may recertify a BOB that another 
gasoline manufacturer has specified blending instructions for 
oxygenate(s) under Sec.  1090.710(a)(5) for a different type or amount 
of oxygenate, including gasoline recertification to contain no 
oxygenate, if the recertifying gasoline manufacturer meets all the 
requirements of this section.
    (2) A gasoline manufacturer must comply with applicable requirements 
of this part and incur deficits to be included in their compliance 
calculations in Sec.  1090.700 for each facility at which the gasoline 
manufacturer recertifies BOB.
    (3) Unless otherwise required under this part, a gasoline 
manufacturer that recertifies 1,000,000 or less gallons of BOB under 
this section at a facility does not need to obtain credits to satisfy 
deficits incurred under this section or arrange for an auditor to 
conduct audits under subpart S of this part for that facility. The 
gasoline manufacturer must still comply with all other applicable 
provisions of this part (e.g., register and submit reports under 
subparts I and J of this part, respectively).
    (4) A party that only recertifies BOB that contains a greater amount 
of a specified oxygenate (e.g., a party adds 15 volume percent DFE 
instead of 10

[[Page 563]]

volume percent to an E10 BOB) or a different oxygenate at an equal or 
greater amount (e.g., a party adds 16 volume percent isobutanol instead 
of 10 volume percent to an E10 BOB) does not incur deficits under this 
section, does not need to submit reports under subpart J of this part, 
and does not need to arrange for an auditor to conduct an audit under 
subpart S of this part. The party must still comply with all other 
applicable provisions of this part (e.g., register and keep records 
under subparts I and M of this part, respectively).
    (b) A gasoline manufacturer that recertifies a BOB under this 
section must calculate sulfur and benzene deficits for each batch and 
the total deficits for sulfur and benzene as follows:
    (1) Sulfur deficits from downstream BOB recertification. Calculate 
the sulfur deficit from BOB recertification for each individual batch of 
BOB recertified as follows:
[GRAPHIC] [TIFF OMITTED] TR04DE20.011

Where:

DS_Oxy_Batch = Sulfur deficit resulting from recertifying the 
          batch of BOB, in ppm-gallons.
VBase = The volume of BOB in the batch being recertified, in 
          gallons.
PTDOxy = The volume fraction of oxygenate that would have 
          been added to the BOB as specified on PTDs.
ACTUALOxy = The volume fraction of oxygenate that was 
          actually added to the BOB. If no oxygenate was added to the 
          BOB, then ACTUALOxy = 0.

    (2) Total sulfur deficit from downstream BOB recertification. 
Calculate the total sulfur deficit from downstream BOB recertification 
for each facility as follows:
[GRAPHIC] [TIFF OMITTED] TR04DE20.012

Where:

DS_Oxy_Total,y = The total sulfur deficit from downstream BOB 
          recertification for compliance period y, in ppm-gallons.
DS_Oxy_Batch_i = The sulfur deficit for batch i of 
          recertified BOB, per paragraph (b)(1) of this section, in ppm-
          gallons.
n = The number of batches of BOB recertified during compliance period y.
i = Individual batch of BOB recertified during compliance period y.

    (3) Benzene deficits from downstream BOB recertification. Calculate 
the benzene deficit from BOB recertification for each individual batch 
of BOB recertified as follows:
[GRAPHIC] [TIFF OMITTED] TR04DE20.013

Where:

DBz_Oxy_Batch = Benzene deficit resulting from recertifying 
          the batch of BOB, in benzene gallons.
VBase = The volume of BOB in the batch being recertified, in 
          gallons.
PTDOxy = The volume fraction of oxygenate that would have 
          been added to the BOB as specified on PTDs.
ACTUALOxy = The volume fraction of oxygenate that was 
          actually added to the

[[Page 564]]

          BOB. If no oxygenate was added to the BOB, then 
          ACTUALOxy = 0.

    (4) Total benzene deficit from downstream BOB recertification. 
Calculate the total benzene deficit from downstream BOB recertification 
for each facility as follows:
[GRAPHIC] [TIFF OMITTED] TR04DE20.014

Where:

DBz_Oxy_Total,y = The total benzene deficit from downstream 
          BOB recertification for compliance period y, in benzene 
          gallons.
DBz_Oxy_Batch_i = The benzene deficit for batch i of 
          recertified BOB, per paragraph (b)(3) of this section, in 
          benzene gallons.
n = The number of batches of BOB recertified during compliance period y.
i = Individual batch of BOB recertified during compliance period y.

    (5) Deficit rounding. The deficits calculated in paragraphs (b)(1) 
through (4) of this section must be rounded and reported to the nearest 
sulfur ppm-gallon or benzene gallon in accordance with Sec.  1090.50, as 
applicable.
    (c) A gasoline manufacturer does not incur a deficit, nor may they 
generate credits, for negative values from the equations in paragraph 
(b) of this section.
    (d) Deficits incurred under this section must be fulfilled in the 
compliance period in which they occur and must not be carried forward 
under Sec.  1090.715.



Sec.  1090.745  Informational annual average calculations.

    (a) A gasoline manufacturer must calculate and report annual average 
sulfur and benzene concentrations for each of their facilities as 
specified in this section. The values calculated and reported under this 
section are not used to demonstrate compliance with average standards 
under this part.
    (b) A gasoline manufacturer must calculate and report their 
unadjusted average sulfur concentration as follows:
[GRAPHIC] [TIFF OMITTED] TR04DE20.015

Where:

Sa,y = The facility unadjusted average sulfur concentration 
          for compliance period y, in ppm. Round and report 
          Sa,y to two decimal places.
Vi = The volume of gasoline produced or imported in batch i, 
          in gallons.
Si = The sulfur content of batch i, in ppm.
n = The number of batches of gasoline produced or imported during the 
          compliance period.
i = Individual batch of gasoline produced or imported during the 
          compliance period.

    (c) A gasoline manufacturer must calculate and report their net 
average sulfur concentration as follows:
[GRAPHIC] [TIFF OMITTED] TR04DE20.016

Where:

SNET,y = The facility net average sulfur concentration for 
          compliance period y, in ppm. Round and report 
          SNET,y to two decimal places.

[[Page 565]]

CSVy = Compliance sulfur value for compliance period y, per 
          Sec.  1090.700(a)(1), in ppm-gallons.

    (d) A gasoline manufacturer must calculate and report their net 
average benzene concentration as follows:
[GRAPHIC] [TIFF OMITTED] TR04DE20.017

Where:

BNET,y = The facility net average benzene concentration for 
          compliance period y, in volume percent benzene. Round and 
          report BNET,y to two decimal places.
CBVy = Compliance benzene value for compliance period y, per 
          Sec.  1090.700(b)(1)(i), in benzene gallons.



                         Subpart I_Registration



Sec.  1090.800  General provisions.

    (a) Who must register. The following parties must register with EPA 
prior to engaging in any activity under this part:
    (1) Fuel manufacturers, including:
    (i) Gasoline manufacturers.
    (ii) Diesel fuel manufacturers.
    (iii) ECA marine fuel manufacturers.
    (iv) Certified butane blenders.
    (v) Certified pentane blenders.
    (vi) Transmix processors.
    (2) Oxygenate blenders.
    (3) Oxygenate producers, including DFE producers.
    (4) Certified pentane producers.
    (5) Certified ethanol denaturant producers.
    (6) Distributors, carriers, and pipeline operators that are part of 
the 500 ppm LM fuel distribution chain under a compliance plan submitted 
under Sec.  1090.515(g).
    (7) Independent surveyors.
    (8) Auditors.
    (9) Third parties that submit reports on behalf of any regulated 
party under this part. Such parties must register and associate their 
registration with the regulated party for whom they are reporting.
    (b) Dates for registration. The deadlines for registration are as 
follows:
    (1) New registrants. Except as specified in paragraph (b)(2) of this 
section, a party not currently registered with EPA must register with 
EPA no later than 60 days in advance of the first date that such party 
engages in any activity under this part requiring registration under 
paragraph (a) of this section.
    (2) Existing registrants. Any party that is already registered with 
EPA under 40 CFR part 80 as of January 1, 2021, is deemed to be 
registered for purposes of this part, except that such party is 
responsible for reviewing and updating their registration information 
consistent with the requirements of this part, as specified in paragraph 
(c) of this section.
    (c) Updates to registration. A registered party must submit updated 
registration information to EPA within 30 days of any occasion when the 
registration information previously supplied becomes incomplete or 
inaccurate.
    (d) RCO submission. Registration information must be submitted by an 
RCO. The RCO may delegate responsibility to a person who is familiar 
with the requirements of this part and who is no lower in the 
organization than a fuel manufacturing facility manager, or equivalent.
    (e) Forms and procedures for registration. All registrants must use 
forms and procedures specified by EPA.
    (f) Company and facility identification. EPA will provide 
registrants with company and facility identifiers to be used for 
recordkeeping and reporting under this part.
    (g) English language. Registration information submitted to EPA must 
be in English.



Sec.  1090.805  Contents of registration.

    (a) General information required for all registrants. A party 
required to register under this part must submit all the following 
general information to EPA:
    (1) Company information. For the company of the party, all the 
following information:

[[Page 566]]

    (i) The company name.
    (ii) Company address, which must be the physical address of the 
business (i.e., not a post office box).
    (iii) Mailing address, if different from company address.
    (iv) Name, title, telephone number, and email address of an RCO.
    (2) Facility information. For each separate facility, all the 
following information:
    (i) The facility name.
    (ii) The physical location of the facility.
    (iii) A contact name, email address, and telephone number for the 
facility.
    (iv) The type of facility.
    (3) Location of records. For each separate facility, or for each 
importer's operations in a single PADD, all the following information:
    (i) Whether records are kept on-site or off-site of the facility, or 
for an importer, the registered address.
    (ii) If records are kept off-site, the primary off-site storage 
name, physical location, contact name, and telephone number.
    (4) Activities. A description of the activities that are engaged in 
by the company and its facilities (e.g., refining, importing, etc.).
    (b) Additional information required for certified pentane producers. 
In addition to the information in paragraph (a) of this section, a 
certified pentane producer must also submit the following information:
    (1) A description of the production facility that demonstrates that 
the facility is capable of producing certified pentane that is compliant 
with the requirements of this part without significant modifications to 
the existing facility.
    (2) A description of how certified pentane will be shipped from the 
production facility to the certified pentane blender(s) and the 
associated quality assurance practices that demonstrate that 
contamination during distribution can be adequately controlled so as not 
to cause certified pentane to be in violation of the standards in this 
part.



Sec.  1090.810  Voluntary cancellation of company or facility registration.

    (a) Criteria for voluntary cancellation. A party may request 
cancellation of the registration of the company or any of its facilities 
at any time. Such request must use forms and procedures specified by 
EPA.
    (b) Effect of voluntary cancellation. A party whose registration is 
canceled:
    (1) Will still be liable for violation of any requirements under 
this part.
    (2) Will not be listed on any public list of actively registered 
companies that is maintained by EPA.
    (3) Will not have access to any of the electronic reporting systems 
associated with this part.
    (4) Will still be required to meet any applicable requirements under 
this part (e.g., the recordkeeping provisions under subpart M of this 
part).
    (c) Re-registration. If a party whose registration has been 
voluntarily cancelled wants to re-register, they must do all the 
following:
    (1) Notify EPA of their intent to re-register.
    (2) Provide any required information and correct any identified 
deficiencies.
    (3) Refrain from initiating a new registration unless directed to do 
so by EPA.
    (4) Submit updated information as needed.



Sec.  1090.815  Deactivation (involuntary cancellation) of registration.

    (a) Criteria for deactivation. EPA may deactivate the registration 
of any party, or any of a party's facilities, required to register under 
this part, using the process specified in paragraph (b) of this section, 
if any of the following criteria are met:
    (1) The party has not accessed their account or engaged in any 
registration or reporting activity within the most recent 24 months.
    (2) The party has failed to comply with the registration 
requirements of this subpart.
    (3) The party has failed to submit any required notification or 
report within 30 days of the required submission date.
    (4) Any required attest engagement has not been received within 30 
days of the required submission date.
    (5) The party fails to pay a penalty or to perform any requirement 
under the terms of a court order, administrative

[[Page 567]]

order, consent decree, or administrative settlement between the party 
and EPA.
    (6) The party submits false or incomplete information.
    (7) The party denies EPA access or prevents EPA from completing 
authorized activities under section 114 or 208 of the Clean Air Act (42 
U.S.C. 7414 or 7542) despite presenting a warrant or court order. This 
includes a failure to provide reasonable assistance.
    (8) The party fails to keep or provide the records required under 
subpart M of this part.
    (9) The party otherwise circumvents the intent of the Clean Air Act 
or of this part.
    (b) Process for deactivation. Except as specified in paragraph (c) 
of this section, EPA will use the following process whenever it decides 
to deactivate the registration of a party:
    (1) EPA will provide written notification to the RCO identifying the 
reasons or deficiencies for which EPA intends to deactivate the party's 
registration. The party will have 30 calendar days from the date of the 
notification to correct the deficiencies identified or explain why there 
is no need for corrective action.
    (2) If the basis for EPA's notice of intent to deactivate 
registration is the absence of activity under paragraph (a)(1) of this 
section, a stated intent to engage in activity will be sufficient to 
avoid deactivation of registration.
    (3) If the party does not correct identified deficiencies under 
paragraphs (a)(2) through (9) of this section, EPA may deactivate the 
party's registration without further notice to the party.
    (c) Immediate deactivation. In instances in which public health, 
public interest, or safety requires, EPA may deactivate the registration 
of the party without any notice to the party. EPA will provide written 
notification to the RCO identifying the reason(s) EPA deactivated the 
registration of the party.
    (d) Effect of deactivation. A party whose registration is 
deactivated:
    (1) Will still be liable for violation of any requirement under this 
part.
    (2) Will not be listed on any public list of actively registered 
companies that is maintained by EPA.
    (3) Will not have access to any of the electronic reporting systems 
associated with this part.
    (4) Will still be required to meet any applicable requirements under 
this part (e.g., the recordkeeping provisions under subpart M of this 
part).
    (e) Re-registration. If a party whose registration has been 
deactivated wishes to re-register, they must do all the following:
    (1) Notify EPA of their intent to re-register.
    (2) Provide any required information and correct any identified 
deficiencies.
    (3) Refrain from initiating a new registration unless directed to do 
so by EPA.
    (4) Remedy the circumstances that caused the party to be deactivated 
in the first place.
    (5) Submit updated information as needed.



Sec.  1090.820  Changes of ownership.

    (a) When a company or any of its facilities will change ownership, 
the company must notify EPA within 30 days after the date of the change 
in ownership.
    (b) The notification required under paragraph (a) of this section 
must include all the following:
    (1) The effective date of the transfer of ownership of the company 
or facility and a summary of any changes to the registration information 
for the affected companies and facilities.
    (2) Documents that demonstrate the sale or change in ownership of 
the company or facility.
    (3) A letter, signed by an RCO from the company that currently owns 
or will own the company or facility and, if possible, an RCO from the 
company that previously registered the company or facility that details 
the effective date of the transfer of ownership of the company or 
facility and summarizes any changes to the registration information.
    (4) Any additional information requested by EPA to complete the 
change in registration.

[[Page 568]]



                           Subpart J_Reporting



Sec.  1090.900  General provisions.

    (a) Forms and procedures for reporting. (1) All reporting, including 
all transacting of credits under this part, must be submitted 
electronically using forms and procedures specified by EPA.
    (2) Values must be reported in the units (e.g., gallons, ppm, etc.) 
and to the number of decimal places specified in this part or in 
reporting formats and procedures, whichever is more precise.
    (3) Reported volumes must be temperature-corrected in accordance 
with Sec.  1090.1350(d).
    (4) Report values as specified in Sec.  1090.1335(e).
    (b) English language. All reports submitted under this subpart must 
be submitted in English.
    (c) Report deadlines. All annual, batch, and credit transaction 
reports required under this subpart, except attest engagement reports, 
must be submitted by March 31 for the preceding compliance period (e.g., 
reports covering the calendar year 2021 must be submitted to EPA by no 
later than March 31, 2022). Attest engagement reports must be submitted 
by June 1 for the preceding compliance period (e.g., attest engagement 
reports covering calendar year 2021 must be submitted to EPA by no later 
than June 1, 2022). Independent survey quarterly reports must be 
submitted by the deadlines in Table 1 to paragraph (a)(4) in Sec.  
1090.925.
    (d) RCO submission. Reports must be signed and submitted by an RCO 
or their delegate of the RCO.



Sec.  1090.905  Annual, batch, and credit transaction reporting for gasoline manufacturers.

    (a) Annual compliance demonstration for sulfur. For each compliance 
period, a gasoline manufacturer must submit a report for each of their 
facilities that includes all the following information:
    (1) Company-level reporting. For the company, as applicable:
    (i) The EPA-issued company and facility identifiers.
    (ii) Provide information for sulfur credits, and separately by 
compliance period of creation, as follows:
    (A) The number of sulfur credits owned at the beginning of the 
compliance period.
    (B) The number of sulfur credits that expired at the end of the 
compliance period.
    (C) The number of sulfur credits that will be carried over into the 
next compliance period.
    (D) Any other information as EPA may require in order to administer 
reporting systems.
    (2) Facility-level reporting. For each refinery or importer, as 
applicable:
    (i) The EPA-issued company and facility identifiers.
    (ii) The compliance sulfur value, per Sec.  1090.700(a)(1), in ppm-
gallons.
    (iii) The total volume of gasoline produced or imported, in gallons.
    (iv) Provide information for sulfur credits, and separately by 
compliance period of creation, as follows:
    (A) The number of sulfur credits generated during the compliance 
period.
    (B) The number of sulfur credits retired during the compliance 
period.
    (C) The sulfur credit deficit that was carried over from the 
previous compliance period.
    (D) The sulfur credit deficit that will be carried over into the 
next compliance period.
    (E) The total sulfur deficit from downstream BOB recertification, 
per Sec.  1090.740(b)(2).
    (v) The unadjusted average sulfur concentration, per Sec.  
1090.745(b), in ppm.
    (vi) The net average sulfur concentration, per Sec.  1090.745(c), in 
ppm.
    (vii) Any other information as EPA may require in order to 
administer reporting systems.
    (b) Annual compliance demonstration for benzene. For each compliance 
period, a gasoline manufacturer must submit a report for each of their 
facilities that includes all the following information:
    (1) Company-level reporting. For the company, as applicable:
    (i) The EPA-issued company and facility identifiers and compliance 
level.
    (ii) Provide information for benzene credits, and separately by 
compliance period of creation, as follows:
    (A) The number of benzene credits owned at the beginning of the 
compliance period.

[[Page 569]]

    (B) The number of benzene credits that expired at the end of the 
compliance period.
    (C) The number of benzene credits that will be carried over into the 
next compliance period.
    (D) Any other information as EPA may require in order to administer 
reporting systems.
    (2) Facility-level reporting. For each fuel manufacturing facility 
or importer, as applicable:
    (i) The EPA-issued company and facility identifiers.
    (ii) The compliance benzene value, per Sec.  1090.700(b)(1)(i), in 
benzene gallons.
    (iii) The total volume of gasoline produced or imported, in gallons.
    (iv) The average benzene concentration, per Sec.  1090.700(b)(3), in 
percent volume. For an importer, report the average benzene 
concentration for each aggregated import facility.
    (v) The net average benzene concentration, per Sec.  1090.745(d), in 
percent volume.
    (vi) Provide information for benzene credits, and separately by 
compliance period of creation, as follows:
    (A) The number of benzene credits generated during the compliance 
period.
    (B) The number of benzene credits retired during the compliance 
period.
    (C) The benzene credit deficit that was carried over from the 
previous compliance period
    (D) The benzene credit deficit that will be carried over into the 
next compliance period.
    (E) The total benzene deficit from downstream BOB recertification, 
per Sec.  1090.740(b)(4).
    (vii) Any other information as EPA may require in order to 
administer reporting systems.
    (c) Batch reporting. A gasoline manufacturer must report the 
following information for each of their facilities on a per-batch basis 
for gasoline and gasoline regulated blendstocks:
    (1) For all gasoline for which the gasoline manufacturer has not 
accounted for oxygenate added downstream under Sec.  1090.710:
    (i) The EPA-issued company and facility identifiers.
    (ii) The batch number.
    (iii) The date the batch was produced or imported.
    (iv) The batch volume, in gallons.
    (v) The designation of the gasoline as RFG, CG, RFG ``Intended for 
Oxygenate Blending'', or CG ``Intended for Oxygenate Blending''.
    (vi) The tested sulfur content of the batch separately for per-
gallon and average compliance, in ppm, and the test method used to 
measure the sulfur content.
    (vii) The tested benzene content of the batch, as a volume 
percentage, and the test method used to measure the benzene content.
    (viii) For all batches of summer gasoline:
    (A) The applicable RVP standard, as specified in Sec.  1090.215.
    (B) The tested RVP of the batch, in psi, and the test method used to 
measure the RVP. If the gasoline is Summer RFG that is designated as 
``Intended for Oxygenate Blending'' under Sec.  1090.1010(a)(4), report 
the tested RVP for the hand blend.
    (ix) If the gasoline contains oxygenate, the type and tested content 
of each oxygenate, as a volume percentage, and the test method used to 
measure the content of each oxygenate.
    (2) For BOB for which the gasoline manufacturer has accounted for 
oxygenate added downstream under Sec.  1090.710:
    (i) The EPA-issued company and facility identifiers.
    (ii) The batch identification.
    (iii) The date the batch of BOB was produced or imported.
    (iv) The batch volume, in gallons. This volume is the sum of the 
produced or imported BOB volume plus the anticipated volume from the 
addition of oxygenate downstream that the gasoline manufacturer 
specified to be blended with the BOB.
    (v) The designation of the BOB (CBOB or RBOB) used to prepare the 
hand blend of BOB and oxygenate under Sec.  1090.1340.
    (vi) The tested sulfur content for both the BOB and the hand blend 
of BOB and oxygenate prepared under Sec.  1090.1340, and the test method 
used to measure the sulfur content.
    (vii) The tested benzene content for the hand blend of BOB and 
oxygenate

[[Page 570]]

prepared under Sec.  1090.1340, and the test method used to measure the 
benzene content.
    (viii) For all batches of summer BOB:
    (A) The applicable RVP standard, as specified in Sec.  1090.215, for 
the neat CBOB, or hand blend of RBOB and oxygenate prepared under Sec.  
1090.1340.
    (B) The tested RVP for the neat CBOB or hand blend of RBOB and 
oxygenate prepared under Sec.  1090.1340, in psi, and the test method 
used to measure the RVP.
    (ix) The type and content of each oxygenate, as a volume percentage, 
in the hand blend of BOB and oxygenate prepared under Sec.  1090.1340, 
and, if measured, the test method used for each oxygenate.
    (3) For blendstock added to PCG by a gasoline manufacturer complying 
by subtraction under Sec.  1090.1320(a)(1):
    (i) For the PCG prior to the addition of blendstock:
    (A) The EPA-issued company and facility identifiers for the facility 
at which the PCG is blended to produce a new batch.
    (B) The batch number assigned by the facility at which the PCG is 
blended to produce a new batch.
    (C) The date the batch was received or, for PCG that was not 
received from another company, the date the PCG was designated to be 
used to produce a new batch of gasoline.
    (D) The batch volume, including the volume of any oxygenate that 
would have been added to the PCG, as a negative number in gallons.
    (E) The designation of the PCG.
    (F) The tested sulfur content of the batch, in ppm, and the test 
method used to measure the sulfur content. If the PCG is a BOB, report 
the tested sulfur content of the hand blend prepared under Sec.  
1090.1340.
    (G) The tested benzene content of the batch, as a volume percentage, 
and the test method used to measure the benzene content. If the PCG is a 
BOB, report the tested benzene content of the hand blend prepared under 
Sec.  1090.1340.
    (H) For all batches of summer gasoline or BOB:
    (1) The applicable RVP standard, as specified in Sec.  1090.215.
    (2) The tested RVP of the batch, in psi, and the test method used to 
measure the RVP.
    (I) If the PCG contains oxygenate, the type and tested content of 
each oxygenate, as a volume percentage, and the test method used to 
measure the content of each oxygenate.
    (J) Identification of the batch as PCG.
    (ii) For the batch of gasoline or BOB produced using PCG and 
blendstock:
    (A) For batches of finished gasoline or neat BOB, all the 
information specified in paragraph (c)(1) of this section.
    (B) For batches of BOB in which the oxygenate to be blended with the 
BOB is included in the gasoline manufacturer's compliance calculations, 
all the information specified in paragraph (c)(2) of this section.
    (4) For blendstock(s) added to PCG by a gasoline manufacturer 
complying by addition under Sec.  1090.1320(a)(2), report each 
blendstock as a separate batch and all the following:
    (i) For the blendstock, the sulfur content and benzene content of 
the batch.
    (ii) For batches produced by adding blendstock to PCG, the sulfur 
content, oxygenate type and amount (unless not required under Sec.  
1090.1310(e)), and for summer gasoline, RVP, of the batch.
    (5) For certified butane blended by a certified butane blender or 
certified pentane blended by a certified pentane blender:
    (i) For the certified butane or certified pentane batch:
    (A) The batch number.
    (B) The date the batch was received by the blender.
    (C) The volume of certified butane or certified pentane blended, in 
gallons.
    (D) The designation of the batch (certified butane or certified 
pentane).
    (E) The volume percentage of butane in butane batches, or pentane in 
pentane batches, provided by the certified butane or certified pentane 
supplier.
    (F) The sulfur content of the batch, in ppm, provided by the 
certified butane or certified pentane supplier.
    (G) The benzene content of the batch, in volume percent, provided by 
the certified butane or certified pentane supplier.

[[Page 571]]

    (ii) For the batch of blended product (i.e., PCG plus butane or PCG 
plus pentane):
    (A) The batch number.
    (B) The date the batch was produced.
    (C) The batch volume, in gallons.
    (D) The designation of the blended product.
    (E) For a new batch of gasoline (e.g., a blended gasoline containing 
certified butane and PCG) that is summer gasoline or summer BOB, the 
tested RVP of the batch, in psi, and the test method used to measure the 
RVP.
    (6) For gasoline produced by adding any blendstocks to TGP:
    (i) For each batch of gasoline produced with TGP, the sulfur content 
and for summer gasoline, RVP, of the batch.
    (ii) For blendstocks added to TGP, a transmix processor or blending 
manufacturer must treat the TGP like PCG and report one of the 
following:
    (A) The information specified in paragraph (c)(3) of this section.
    (B) The information specified in paragraph (c)(4) of this section.
    (7) For GTAB:
    (i) The EPA-issued company and facility identifiers.
    (ii) The batch number.
    (iii) The date the batch was imported.
    (iv) The batch volume, in gallons.
    (v) The designation of the product as GTAB.
    (8) For each batch of gasoline produced by a transmix processor or 
blending manufacturer from only TGP or both TGP and PCG under Sec.  
1090.505:
    (i) The EPA-issued company and facility identifiers.
    (ii) The batch number.
    (iii) The date the batch was produced.
    (iv) The batch volume, in gallons.
    (v) The designation of the gasoline.
    (vi) The tested sulfur content of the batch, in ppm, and the test 
method used to measure the sulfur content.
    (vii) For summer gasoline:
    (A) The applicable RVP standard in Sec.  1090.215.
    (B) The tested RVP of the batch, in psi, and the test method used to 
measure the RVP.
    (9) Any other information as EPA may require in order to administer 
reporting systems.
    (d) Credit transactions. Any party that is required to demonstrate 
annual compliance under paragraph (a) or (b) of this section must submit 
information related to individual transactions involving sulfur and 
benzene credits, including all the following:
    (1) The generation, purchase, sale, or retirement of such credits.
    (2) If any credits were obtained from or transferred to other fuel 
manufacturers, and for each other party, their name and EPA-issued 
company identifier, the number of credits obtained from or transferred 
to the other party, and the year the credits were generated.
    (3) Any other information as EPA may require in order to administer 
reporting systems.



Sec.  1090.910  Reporting for gasoline manufacturers that recertify BOB to gasoline.

    A party that recertifies BOB under Sec.  1090.740 must report the 
information of this section, as applicable.
    (a) Batch reporting. (1) A party that recertifies a BOB under Sec.  
1090.740 with less oxygenate than specified by the BOB manufacturer must 
report the following for each batch:
    (i) The EPA-issued company and facility identifiers for the 
recertifying party.
    (ii) The batch number assigned by the recertifying party.
    (iii) The date the batch was recertified.
    (iv) The batch volume, as a negative number in gallons. The volume 
is the amount of oxygenate that the recertifying gasoline manufacturer 
did not blend with the BOB.
    (v) The designation of the batch.
    (vi) A sulfur content of 11 ppm.
    (vii) A benzene content of 0.68 volume percent.
    (viii) The type and content of each oxygenate, as a volume 
percentage.
    (ix) The sulfur deficit for the batch calculated under Sec.  
1090.740(b)(1).
    (x) The benzene deficit for the batch calculated under Sec.  
1090.740(b)(3).
    (2) A party that recertifies a BOB under Sec.  1090.740 with more 
oxygenate than specified by the BOB manufacturer does not need to report 
the batch.

[[Page 572]]

    (b) Annual sulfur and benzene compliance reporting. A party that 
recertifies a BOB under Sec.  1090.740 must include any deficits 
incurred from recertification in reports under Sec.  1090.905(a) and 
(b).
    (c) Credit transactions. A party that recertifies a BOB under Sec.  
1090.740 must report any credit transactions under Sec.  1090.905(d).



Sec.  1090.915  Batch reporting for oxygenate producers and importers.

    An oxygenate producer, for each of their production facilities, or 
an importer for the oxygenate they import, must submit a report for each 
compliance period that includes all the following information:
    (a) The EPA-issued company and facility identifiers.
    (b) The total volume of oxygenate produced or imported.
    (c) For each batch of oxygenate produced or imported during the 
compliance period, all the following:
    (1) The batch number.
    (2) The date the batch was produced or imported.
    (3) One of the following product types:
    (i) Denatured ethanol using certified ethanol denaturant complying 
with Sec.  1090.275.
    (ii) Denatured ethanol from non-certified ethanol denaturant.
    (iii) A specified oxygenate other than ethanol (e.g., isobutanol).
    (4) The volume of the batch, in gallons.
    (5) The tested sulfur content of the batch, in ppm, and the test 
method used to measure the sulfur content.
    (d) Any other information as EPA may require in order to administer 
reporting systems.



Sec.  1090.920  Reports by certified pentane producers.

    A certified pentane producer must submit a report for each facility 
at which certified pentane was produced or imported that contains all 
the following information:
    (a) The EPA-issued company and facility identifiers.
    (b) For each batch of certified pentane produced or imported during 
the compliance period, all the following:
    (1) The batch number.
    (2) The date the batch was produced or imported.
    (3) The batch volume, in gallons.
    (4) The tested pentane content of the batch, as a volume percentage, 
and the test method used to measure the pentane content.
    (5) The tested sulfur content of the batch, in ppm, and the test 
method used to measure the sulfur content.
    (6) The tested benzene of the batch, as a volume percentage, and the 
test method used to measure the benzene content.
    (7) The tested RVP of the batch, in psi, and the test method used to 
measure the RVP.
    (c) Any other information as EPA may require in order to administer 
reporting systems.



Sec.  1090.925  Reports by independent surveyors.

    (a) General procedures. An independent surveyor must meet the 
following requirements:
    (1) Electronically submit any plans, notifications, or reports 
required under this part using forms and procedures specified by EPA.
    (2) For each report required under this section, affirm that the 
survey was conducted in accordance with an EPA-approved survey plan and 
that the survey results are accurate.
    (3) Include EPA-issued company identifiers on each report required 
under this section.
    (4) Submit quarterly reports required under paragraphs (b) and (d) 
of this section by the following deadlines:

                           Table 1 to Paragraph (a)(4)--Quarterly Reporting Deadlines
----------------------------------------------------------------------------------------------------------------
            Calendar quarter                    Time period covered              Quarterly report deadline
----------------------------------------------------------------------------------------------------------------
Quarter 1...............................  January 1-March 31.............  June 1.
Quarter 2...............................  April 1-June 30................  September 1.
Quarter 3...............................  July 1-September 30............  December 1.
Quarter 4...............................  October 1-December 31..........  March 31.
----------------------------------------------------------------------------------------------------------------


[[Page 573]]

    (b) NFSP quarterly reporting. An independent surveyor conducting the 
NFSP under Sec.  1090.1405 must submit the following information 
quarterly, as applicable:
    (1) For each retail outlet sampled by the independent surveyor:
    (i) The identification information for the retail outlet, as 
assigned by the surveyor in a consistent manner and as specified in the 
survey plan.
    (ii) The displayed fuel manufacturer brand name at the retail 
outlet, if any.
    (iii) The physical location (i.e., address) of the retail outlet.
    (2) For each gasoline sample collected by the independent surveyor:
    (i) A description of the labeling of the fuel dispenser(s) (e.g., 
``E0'', ``E10'', ``E15'', etc.) from which the independent surveyor 
collected the sample.
    (ii) The date and time the independent surveyor collected the 
sample.
    (iii) The test results for the sample, and the test methods used, as 
determined by the independent surveyor, including the following 
parameters:
    (A) The oxygen content, in weight percent.
    (B) The type and amount of each oxygenate, by weight and volume 
percent.
    (C) The sulfur content, in ppm.
    (D) The benzene content, in volume percent.
    (E) The specific gravity.
    (F) The RVP in psi, if tested.
    (G) The aromatic content in volume percent, if tested.
    (H) The olefin content in volume percent, if tested.
    (I) The distillation parameters, if tested.
    (3) For each diesel sample collected at a retail outlet by the 
independent surveyor:
    (i) A description of the labeling of the fuel dispenser(s) (e.g., 
``ULSD'') from which the independent surveyor collected the sample.
    (ii) The date and time the independent surveyor collected the 
sample.
    (iii) The tested sulfur content of the sample, and the test method 
used, as determined by the independent surveyor, in ppm.
    (4) Any other information as EPA may require in order to administer 
reporting systems.
    (c) NFSP annual reporting. An independent surveyor conducting the 
NFSP under Sec.  1090.1405 must submit the following information 
annually by March 31.
    (1) An identification of the parties that participated in the survey 
during the compliance period.
    (2) An identification of each geographic area included in a survey.
    (3) Summary statistics for each identified geographic area, 
including the following:
    (i) The number of samples collected and tested.
    (ii) The mean, median, and range expressed in appropriate units for 
each measured gasoline and diesel parameter.
    (iii) The standard deviation for each measured gasoline and diesel 
parameter.
    (iv) The estimated compliance rate for each measured gasoline and 
diesel parameter subject to a per-gallon standard in subpart C or D of 
this part.
    (v) A summary of potential non-compliance issues.
    (4) Any other information as EPA may require in order to administer 
reporting systems.
    (d) NSTOP quarterly reporting. An independent surveyor conducting 
the NSTOP under Sec.  1090.1450 must submit the following information 
quarterly, as applicable:
    (1) For each gasoline manufacturing facility sampled by the 
independent surveyor:
    (i) The EPA-issued company and facility identifiers for the gasoline 
manufacturer and the gasoline manufacturing facility.
    (ii) [Reserved]
    (2) For each gasoline sample collected by the independent surveyor:
    (i) The designation of the gasoline.
    (ii) The date and time the independent surveyor collected the 
sample.
    (iii) The batch number or the sample identification number as 
assigned by the independent surveyor in a consistent manner and as 
specified in the survey plan.
    (iv) A description of any instance in which the gasoline 
manufacturer did not follow the applicable sampling procedures.

[[Page 574]]

    (v) The test results for the sample, and the test methods used, as 
determined by the independent surveyor, including the following 
parameters:
    (A) The sulfur content, in ppm.
    (B) The benzene content, in volume percent.
    (C) The RVP in psi, if tested.
    (vi) The test results for the sample, and the test methods used, as 
determined by the gasoline manufacturer, including the following 
parameters:
    (A) The sulfur content, in ppm.
    (B) The benzene content, in volume percent.
    (C) The RVP in psi, if tested.
    (vii) If available, the test results for the sample, and the test 
methods used, as determined by EPA's National Vehicle and Fuel Emissions 
Laboratory, including the following parameters:
    (A) The sulfur content, in ppm.
    (B) The benzene content, in volume percent.
    (C) The RVP in psi, if tested.
    (viii) The determined site precision under Sec.  1090.1450(c)(10)(i) 
and the test performance index under Sec.  1090.1450(c)(10)(ii) for each 
method and instrument that the gasoline manufacturer used to test the 
sample.
    (ix) The reproducibility of each method that the gasoline 
manufacturer used to test the sample.
    (x) Any applicable correlation equations used to compare the 
gasoline manufacturer's test results to the independent surveyor's test 
results.
    (3) Any other information as EPA may require in order to administer 
reporting systems.



Sec.  1090.930  Reports by auditors.

    (a) Attest engagement reports required under subpart S of this part 
must be submitted by an independent auditor registered with EPA and 
associated with a company, or companies, through registration under 
subpart I of this part. Each attest engagement must clearly identify the 
company and compliance level (e.g., facility), time period, and scope 
covered by the report. Attest engagement reports covered by this section 
include those required under this part, and under 40 CFR part 80, 
subpart M, beginning with the report due June 1, 2022.
    (b) An attest engagement report must be submitted to EPA covering 
each compliance period by June 1 of the following calendar year. The 
auditor must make the attest engagement available to the company for 
which it was performed.
    (c) The attest engagement must comply with subpart S of this part 
and the attest engagement report must clearly identify the methodologies 
followed and any findings, exceptions, and variances.
    (d) A single attest engagement submission by the auditor may include 
procedures performed under this part and under 40 CFR part 80, subpart 
M. If a single submission method is used, the auditor must clearly and 
separately describe the procedures and findings for each program.
    (e) The auditor must submit written acknowledgement from the RCO 
that the gasoline manufacturer has reviewed the attest engagement 
report.



Sec.  1090.935  Reports by diesel fuel manufacturers.

    (a) Batch reporting. (1) For each compliance period, a ULSD 
manufacturer must submit the following information:
    (i) The EPA-issued company and facility identifiers for the ULSD 
manufacturer.
    (ii) The highest sulfur content observed for a batch of ULSD 
produced during the compliance period on a company level, in ppm.
    (iii) The average sulfur concentration of all batches produced 
during the compliance period on a company level, in ppm.
    (iv) A list of all batches of ULSD that exceeded the sulfur standard 
in Sec.  1090.305(b) by facility. For each such batch, report the 
following:
    (A) The batch number.
    (B) The date the batch was produced.
    (C) The volume of the batch, in gallons.
    (D) The sulfur content of the batch, in ppm.
    (E) The corrective action taken, if any.
    (b) [Reserved]

[[Page 575]]



              Subpart K_Batch Certification and Designation



Sec.  1090.1000  Batch certification requirements.

    (a) General provisions. (1) A fuel manufacturer, fuel additive 
manufacturer, or regulated blendstock producer must certify batches of 
fuel, fuel additive, or regulated blendstock as specified in this 
section.
    (2) A fuel manufacturer, fuel additive manufacturer, or regulated 
blendstock producer does not need to certify fuel, fuel additive, or 
regulated blendstock that is exempt under subpart G of this part.
    (3)(i) For purposes of this part, the volume of a batch is one of 
the following:
    (A) The sum of all shipments or transfers of fuel, fuel additive, or 
regulated blendstock out of the tank or vessel in which the fuel, fuel 
additive, or regulated blendstock was certified.
    (B) The entire volume of a tank or vessel may be certified as a 
single batch. In such cases, any heel left in the tank or vessel after 
shipments of the batch becomes PCG.
    (ii) If a volume of fuel, fuel additive, or regulated blendstock is 
placed in a tank, certified (if not previously certified), and is not 
altered in any manner, then it is considered to be the same batch even 
if several shipments or transfers are made out of that tank.
    (iii) Batch volumes must be temperature-corrected in accordance with 
Sec.  1090.1350(d).
    (4) For fuel produced at a facility that has an in-line blending 
waiver under Sec.  1090.1315, the volume of the batch is the volume of 
product that is homogeneous under the requirements in Sec.  1090.1337 
and is produced during a period not to exceed 10 days.
    (5) A fuel manufacturer must certify each batch of fuel at the 
facility where the fuel is produced or at a facility that is under the 
complete control of the fuel manufacturer before they transfer custody 
or title of the fuel to any other person.
    (6) No person may sell, offer for sale, distribute, offer to 
distribute, supply, offer for supply, dispense, store, transport, or 
introduce into commerce gasoline, diesel fuel, or ECA marine fuel that 
is not certified under this section.
    (b) Gasoline. (1) A gasoline manufacturer must certify gasoline as 
specified in paragraph (b)(2) of this section prior to introduction into 
commerce.
    (2) To certify batches of gasoline, a gasoline manufacturer must 
comply with all the following:
    (i) Register with EPA as a refiner, blending manufacturer, importer, 
transmix processor, certified butane blender, or certified pentane 
blender under subpart I of this part, as applicable, prior to producing 
gasoline.
    (ii) Ensure that each batch of gasoline meets the applicable 
requirements of subpart C of this part using the applicable procedures 
specified in subpart N of this part. A transmix processor must also meet 
all applicable requirements in subpart F of this part to ensure that 
each batch of gasoline meets the applicable requirements in subpart C of 
this part.
    (iii) Assign batch numbers as specified in Sec.  1090.1020.
    (iv) Designate batches of gasoline as specified in Sec.  1090.1010.
    (3) PCG may be mixed with other PCG without re-certification if the 
resultant mixture complies with the applicable standards in subpart C of 
this part and is accurately and clearly designated under Sec.  
1090.1010. Resultant mixtures of PCG are not new batches and should not 
be assigned new batch numbers.
    (4) Any person that mixes summer gasoline with summer or winter 
gasoline that has a different designation must comply with one of the 
following:
    (i) Designate the resultant mixture as meeting the least stringent 
RVP designation of any batch that is mixed. For example, a distributor 
that mixes Summer RFG with 7.8 psi Summer CG must designate the mixture 
as 7.8 psi Summer CG.
    (ii) Determine the RVP of the mixture using the procedures specified 
in subpart N of this part and designate the new batch under Sec.  
1090.1010 to reflect the RVP of the resultant mixture.
    (5) Any person that mixes summer gasoline with winter gasoline to 
transition any storage tank from winter to summer gasoline is exempt 
from the requirement in paragraph (b)(4)(ii) of

[[Page 576]]

this section but must ensure that the gasoline meets the applicable RVP 
standard in Sec.  1090.215.
    (c) Diesel fuel and ECA marine fuel. (1) A diesel fuel or ECA marine 
fuel manufacturer must certify diesel fuel or ECA marine fuel as 
specified in paragraph (c)(2) of this section prior to introducing the 
fuel into commerce.
    (2) To certify batches of diesel fuel or ECA marine fuel, a diesel 
fuel or ECA marine fuel manufacturer must comply with all the following:
    (i) Register with EPA as a refiner, blending manufacturer, importer, 
or transmix processor under subpart I of this part, as applicable, prior 
to producing diesel fuel or ECA marine fuel.
    (ii) Ensure that each batch of diesel fuel or ECA marine fuel meets 
the applicable requirements of subpart D of this part using the 
applicable procedures specified in subpart N of this part. A transmix 
processor must also meet all applicable requirements specified in 
subpart F of this part to ensure that each batch of diesel fuel or ECA 
marine fuel meets the applicable requirements in subpart D of this part.
    (iii) Assign batch numbers as specified in Sec.  1090.1020.
    (iv) Designate batches of diesel fuel as specified in Sec.  
1090.1015.
    (d) Oxygenates. (1) An oxygenate producer must certify oxygenates 
intended to be blended into gasoline as specified in paragraph (d)(2) of 
this section.
    (2) To certify batches of oxygenates, an oxygenate producer must 
comply with all the following:
    (i) Register with EPA as an oxygenate producer under subpart I of 
this part prior to producing or importing oxygenate intended for 
blending into gasoline.
    (ii) Ensure that each batch of oxygenate meets the requirements in 
Sec.  1090.270 by using the applicable procedures specified in subpart N 
of this part.
    (iii) Assign batch numbers as specified in Sec.  1090.1020.
    (iv) Designate batches of oxygenate as intended for blending with 
gasoline as specified in Sec.  1090.1010(c).
    (e) Certified butane. (1) A certified butane producer must certify 
butane intended to be blended by a blending manufacturer under Sec.  
1090.1320 as specified in paragraph (e)(2) of this section.
    (2) To certify batches of certified butane, a certified butane 
producer must comply with all the following:
    (i) Ensure that each batch of certified butane meets the 
requirements in Sec.  1090.250 by using the applicable procedures 
specified in subpart N of this part.
    (A) Testing must occur after the most recent delivery into the 
certified butane producer's storage tank.
    (B) The certified butane producer must provide documentation of the 
test results for each batch of certified butane to the certified butane 
blender.
    (ii) Designate batches of certified butane as intended for blending 
with gasoline as specified in Sec.  1090.1010(d).
    (f) Certified pentane. (1) A certified pentane producer must certify 
pentane intended to be blended by a blending manufacturer under Sec.  
1090.1320 as specified in paragraph (f)(2) of this section.
    (2) To certify batches of certified pentane, a certified pentane 
producer must comply with all the following:
    (i) Register with EPA as a certified pentane producer under subpart 
I of this part prior to producing certified pentane.
    (ii) Ensure that each batch of certified pentane meets the 
requirements in Sec.  1090.255 by using the applicable procedures 
specified in subpart N of this part.
    (A) Testing must occur after the most recent delivery into the 
certified pentane producer's storage tank, before transferring the 
certified pentane batch for delivery.
    (B) The certified pentane producer must provide documentation of the 
test results for each batch of certified pentane to the certified 
pentane blender.
    (iii) Assign batch numbers as specified in Sec.  1090.1020.
    (iv) Designate batches of certified pentane as intended for blending 
with gasoline as specified in Sec.  1090.1010(d).
    (g) Certified ethanol denaturant. (1) A certified ethanol denaturant 
producer must certify certified ethanol denaturant intended to be used 
to make DFE that meets the requirements in Sec.  1090.275 as specified 
in paragraph (g)(2) of this section.

[[Page 577]]

    (2) To certify batches of certified ethanol denaturant, a certified 
ethanol denaturant producer must comply with all the following:
    (i) Register with EPA as a certified ethanol denaturant producer 
under subpart I of this part prior to producing certified ethanol 
denaturant.
    (ii) Ensure that each batch of certified ethanol denaturant meets 
the requirements in Sec.  1090.275 by using the applicable procedures 
specified in subpart N of this part.
    (iii) Assign batch numbers as specified in Sec.  1090.1020.
    (iv) Designate batches of certified ethanol denaturant as intended 
for blending with gasoline as specified in Sec.  1090.1010(e).



Sec.  1090.1005  Designation of batches of fuels, fuel additives,
and regulated blendstocks.

    (a) A fuel manufacturer, fuel additive manufacturer, or regulated 
blendstock producer must designate batches of fuel, fuel additive, or 
regulated blendstock as specified in this subpart.
    (b) A fuel manufacturer, fuel additive manufacturer, or regulated 
blendstock producer must designate the fuel, fuel additive, or regulated 
blendstock prior to the fuel, fuel additive, or regulated blendstock 
leaving the facility where it was produced and must include the 
designations on PTDs as specified in this subpart.
    (c) By designating a batch of fuel, fuel additive, or regulated 
blendstock under this subpart, the designating party is acknowledging 
that the batch is subject to all applicable standards under this part.
    (d) A person must comply with all provisions of this part even if 
they fail to designate or improperly designate a batch of fuel, fuel 
additive, or regulated blendstock.
    (e) No person may use the designation provisions of this subpart to 
circumvent any standard or requirement in this part.



Sec.  1090.1010  Designation requirements for gasoline 
and regulated blendstocks.

    (a) Designation requirements for gasoline manufacturers. A gasoline 
manufacturer must accurately and clearly designate each batch of 
gasoline as follows:
    (1) A gasoline manufacturer must designate each batch of gasoline as 
one of the following fuel types:
    (i) Winter RFG.
    (ii) Summer RFG.
    (iii) Winter RBOB.
    (iv) Summer RBOB.
    (v) Winter CG.
    (vi) Summer CG.
    (vii) Winter CBOB.
    (viii) Summer CBOB.
    (ix) Exempt gasoline under subpart G of this part (including 
additional identifying information).
    (x) California gasoline.
    (2) A gasoline manufacturer must further designate gasoline 
designated as Summer CG or Summer CBOB as follows:
    (i) 7.8 psi Summer CG or Summer CBOB, respectively.
    (ii) 9.0 psi Summer CG or Summer CBOB, respectively.
    (iii) SIP-controlled Summer CG or Summer CBOB, respectively.
    (3) A CBOB or RBOB manufacturer must further designate the CBOB or 
RBOB with the type(s) and amount(s) of oxygenate specified to be blended 
with the CBOB or RBOB as specified in Sec.  1090.710(a)(5).
    (4) In addition to any other applicable designation in this 
paragraph (a), gasoline designed for downstream oxygenate blending for 
which the gasoline manufacturer has not accounted for oxygenate added 
downstream under Sec.  1090.710 must be designated as ``Intended for 
Oxygenate Blending'', along with a designation indicating the type(s) 
and amount(s) of oxygenate to be blended with the gasoline.
    (b) Designation requirements for gasoline distributors and certain 
gasoline blending manufacturers. A gasoline distributor, certified 
butane blender, certified pentane blender, or party that recertifies BOB 
under Sec.  1090.740 must accurately and clearly designate each batch or 
portion of a batch of gasoline for which they transfer custody to 
another facility as follows:
    (1) A distributor must accurately and clearly classify each batch or 
portion of a batch of gasoline as specified by the gasoline manufacturer 
in paragraph (a) of this section.

[[Page 578]]

    (2) Except as specified in paragraph (b)(2)(vii) of this section, a 
distributor, certified butane blender, certified pentane blender, or 
party that recertifies BOB under Sec.  1090.740 may redesignate a batch 
or portion of a batch of gasoline without recertifying the batch or 
portion of a batch as follows:
    (i) Winter RFG or Winter RBOB may be redesignated as either Winter 
CG or Winter CBOB.
    (ii) Winter CG or Winter CBOB may be redesignated as either Winter 
RFG or Winter RBOB.
    (iii) Summer RFG, Summer RBOB, Summer CG, or Summer CBOB may be 
redesignated without recertification to a less stringent RVP 
designation. For example, a distributor could redesignate without 
recertification a portion of a batch of Summer RFG to 7.8 psi Summer CG 
or 9.0 psi Summer CG.
    (iv) Summer RFG, Summer RBOB, Summer CG, or Summer CBOB may be 
redesignated without recertification as either Winter RFG, Winter RBOB, 
Winter CG, or Winter CBOB.
    (v) Summer CG, Summer CBOB, or any winter gasoline may be 
redesignated to either Summer RFG or Summer RBOB, provided the RVP is 
determined using the applicable procedures specified in subpart N of 
this part and the new batch meets the RFG RVP standard specified in 
Sec.  1090.215(a)(3).
    (vi)(A) California gasoline may be redesignated as RFG or CG, with 
appropriate season designation and RVP designation under paragraph (a) 
of this section, if the requirements specified in Sec.  1090.625(d) are 
met.
    (B) California gasoline that is not redesignated under paragraph 
(b)(2)(vi)(A) of this section may instead be recertified as gasoline 
under Sec.  1090.1000(b).
    (vii) CG or RFG must not be redesignated as BOB.
    (3) A distributor, certified butane blender, certified pentane 
blender, or party that recertifies BOB under Sec.  1090.740 that 
redesignates a batch or portion of a batch of gasoline under paragraph 
(b)(2) of this section must accurately and clearly designate the batch 
or portion of the batch of gasoline as specified in paragraph (a) of 
this section.
    (c) Designation requirements for oxygenate producers. An oxygenate 
producer must accurately and clearly designate each batch of oxygenate 
intended for blending with gasoline as one of the following oxygenate 
types:
    (1) DFE.
    (2) The name of the specific oxygenate (e.g., iso-butanol).
    (d) Designation requirements for certified butane and certified 
pentane. A certified butane or certified pentane producer must 
accurately and clearly designate each batch of certified butane or 
certified pentane as one of the following types:
    (1) Certified butane.
    (2) Certified pentane.
    (e) Designation requirements for certified ethanol denaturant. A 
certified ethanol denaturant producer must accurately and clearly 
designate batches of certified ethanol denaturant as ``certified ethanol 
denaturant''.
    (f) Designation requirements for TGP. A transmix processor must 
accurately and clearly designate any TGP that they transfer to any other 
person as ``TGP''.



Sec.  1090.1015  Designation requirements for diesel and distillate fuels.

    (a) Designation requirements for diesel and distillate fuel 
manufacturers. (1) Except as specified in paragraph (a)(3) of this 
section, a diesel fuel or distillate fuel manufacturer must accurately 
and clearly designate each batch of diesel fuel or distillate fuel as at 
least one of the following fuel types:
    (i) ULSD. A diesel fuel manufacturer may also designate ULSD as 15 
ppm MVNRLM diesel fuel.
    (ii) 500 ppm LM diesel fuel.
    (iii) Heating oil.
    (iv) Jet fuel.
    (v) Kerosene.
    (vi) ECA marine fuel.
    (vii) Distillate global marine fuel.
    (viii) Certified NTDF.
    (ix) Exempt diesel fuel or distillate fuel under subpart G of this 
part (including additional identifying information).
    (2) Only a fuel manufacturer that complies with the requirements in 
Sec.  1090.515 may designate fuel as 500 ppm LM diesel fuel.

[[Page 579]]

    (3) Any batch of diesel fuel or distillate fuel that is certified 
and designated as ULSD may also be designated as heating oil, kerosene, 
ECA marine fuel, jet fuel, or distillate global marine fuel if it is 
also suitable for such use.
    (b) Designation requirements for distributors of diesel and 
distillate fuels. A distributor of diesel and distillate fuels must 
accurately and clearly designate each batch of diesel fuel or distillate 
fuel for which they transfer custody as follows:
    (1) A distributor must accurately and clearly designate such diesel 
fuel or distillate fuel by sulfur content while it is in their custody 
(e.g., as 15 ppm or 500 ppm).
    (2) A distributor must accurately and clearly designate such diesel 
fuel or distillate fuel as specified by the diesel fuel or distillate 
fuel manufacturer under paragraph (a) of this section.
    (3) A distributor may redesignate batches or portions of batches of 
diesel fuel or distillate fuel for which they transfer custody to 
another facility without recertifying the batch or portion of the batch 
as follows:
    (i) ULSD that is also suitable for use as kerosene or jet fuel 
(commonly referred to as dual use kerosene) may be designated as ULSD, 
kerosene, or jet fuel (as applicable).
    (ii) ULSD may be redesignated as 500 ppm LM diesel fuel, heating 
oil, kerosene, ECA marine fuel, jet fuel, or distillate global marine 
fuel without recertification if all applicable requirements under this 
part are met for the new fuel designation.
    (iii) California diesel may be redesignated as ULSD if the 
requirements specified in Sec.  1090.625(e) are met.
    (iv) Heating oil, kerosene, ECA marine fuel, or jet fuel may be 
redesignated as ULSD if the fuel meets the ULSD standards in Sec.  
1090.305 and was designated as ULSD under paragraph (a) of this section.
    (v) 500 ppm LM diesel fuel may be redesignated as ECA marine fuel, 
distillate global marine fuel, or heating oil. Any person that 
redesignates 500 ppm LM diesel fuel to ECA marine fuel or distillate 
global marine fuel must maintain records from the producer of the 500 
ppm LM diesel fuel (i.e., PTDs accompanying the fuel under Sec.  
1090.1115) to demonstrate compliance with the 500 ppm sulfur standard in 
Sec.  1090.320(b).
    (vi) Fuel designated as certified NTDF may be redesignated as ULSD 
without recertification if the applicable requirements of 40 CFR 80.1408 
are met.
    (c) ULSD designation limitation. No person may designate distillate 
fuel with a sulfur content greater than the sulfur standard in Sec.  
1090.305(b) as ULSD.



Sec.  1090.1020  Batch numbering.

    (a) A fuel manufacturer, fuel additive manufacturer, or regulated 
blendstock producer must assign a number (the ``batch number'') to each 
batch of gasoline, diesel fuel, oxygenate, certified pentane, or 
certified ethanol denaturant either produced or imported. The batch 
number must, if available, consist of the EPA-assigned company 
registration number of the party that either produced or imported the 
fuel, fuel additive, or regulated blendstock, the EPA-assigned facility 
registration number where the fuel, fuel additive, or regulated 
blendstock was produced or imported, the last two digits of the year 
that the batch was either produced or imported, and a unique number for 
the batch, beginning with the number one (1) for the first batch 
produced or imported each calendar year and each subsequent batch during 
the calendar year being assigned the next sequential number (e.g., 4321-
54321-20-000001, 4321-54321-20-000002, etc.). EPA assigns company and 
facility registration numbers as specified in subpart I of this part.
    (b) Certified butane or certified pentane blended with PCG during a 
period of up to one month may be included in a single batch for purposes 
of reporting to EPA.
    (c) A gasoline manufacturer that recertifies BOBs under Sec.  
1090.740 may include up to a single month's volume as a single batch for 
purposes of reporting to EPA.

[[Page 580]]



                  Subpart L_Product Transfer Documents



Sec.  1090.1100  General requirements.

    (a) General provisions. (1) On each occasion when any person 
transfers custody or title to any product covered under this part, other 
than when fuel is sold or dispensed to the ultimate end user at a retail 
outlet or WPC facility, the transferor must provide the transferee PTDs 
that include the following information:
    (i) The name and address of the transferor.
    (ii) The name and address of the transferee.
    (iii) The volume of the product being transferred.
    (iv) The location of the product at the time of the transfer.
    (v) The date of the transfer.
    (2) The specific designations required for gasoline-related products 
specified in Sec.  1090.1010 or distillate-related products specified in 
Sec.  1090.1015.
    (b) Use of codes. Except for transfers to a truck carrier, retailer, 
or WPC, product codes may be used to convey the information required 
under this subpart, if such codes are clearly understood by each 
transferee.
    (c) Part 80 PTD requirements. For fuel, fuel additive, or regulated 
blendstock subject to 40 CFR part 80, subpart M, a party must also 
include the applicable PTD information required under 40 CFR 80.1453.



Sec.  1090.1105  PTD requirements for exempt fuels.

    (a) In addition to the information required under Sec.  1090.1100, 
on each occasion when any person transfers custody or title to any 
exempt fuel under subpart G of this part, other than when fuel is sold 
or dispensed to the ultimate end user at a retail outlet or WPC 
facility, the transferor must provide the transferee PTDs that include 
the following statements, as applicable:
    (1) National security exemption language. For fuels with a national 
security exemption specified in Sec.  1090.605: ``This fuel is for use 
in vehicles, engines, or equipment under an EPA-approved national 
security exemption only.''
    (2) R&D exemption language. For fuels used for an R&D purpose 
specified in Sec.  1090.610: ``For use in research, development, and 
test programs only.''
    (3) Racing fuel language. For fuels used for racing purposes 
specified in Sec.  1090.615: ``This fuel is for racing purposes only.''
    (4) Aviation fuel language. For fuels used in aircraft specified in 
Sec.  1090.615: ``This fuel is for aviation use only.''
    (5) Territory fuel exemption language. For fuels for use in American 
Samoa, Guam, or the Commonwealth of the Northern Mariana Islands 
specified in Sec.  1090.620: ``This fuel is for use only in Guam, 
American Samoa, or the Northern Mariana Islands.''
    (6) California gasoline language. For California gasoline specified 
in Sec.  1090.625: ``California gasoline''.
    (7) California diesel language. For California diesel specified in 
Sec.  1090.625: ``California diesel''.
    (8) Alaska, Hawaii, Puerto Rico, and U.S. Virgin Islands summer 
gasoline language. For summer gasoline for use in Alaska, Hawaii, Puerto 
Rico, or the U.S. Virgin Islands specified in Sec.  1090.630: ``This 
summer gasoline is for use only in Alaska, Hawaii, Puerto Rico, or the 
U.S. Virgin Islands.''
    (9) Exported fuel language. For exported fuels specified in Sec.  
1090.645: ``This fuel is for export from the United States only.''
    (b) In statements required by paragraph (a) of this section, where 
``fuel'' is designated in a statement, the specific fuel type (for 
example, ``diesel fuel'' or ``gasoline'') may be used in place of the 
word ``fuel''.



Sec.  1090.1110  PTD requirements for gasoline, gasoline additives,
and gasoline regulated blendstocks.

    (a) General requirements. On each occasion when any person transfers 
custody or title of any gasoline, gasoline additive, or gasoline 
regulated blendstock, other than when fuel is sold or dispensed to the 
ultimate end user at a retail outlet or WPC facility, the transferor 
must provide the transferee PTDs that include the following information:
    (1) All applicable information required under Sec.  1090.1100 and 
this section.

[[Page 581]]

    (2) An accurate and clear statement of the applicable designation of 
the gasoline, gasoline additive, or gasoline regulated blendstock under 
Sec.  1090.1010.
    (b) BOB language requirements. For batches of BOB, in addition to 
the information required under paragraph (a) of this section, the 
following information must be included on the PTD:
    (1) Oxygenate type(s) and amount(s). Statements specifying each 
oxygenate type and amount (or range of amounts) for which the BOB was 
certified under Sec.  1090.710(a)(5).
    (2) Summer BOB language requirements. (i) Except as specified in 
paragraph (b)(2)(ii) of this section, for batches of summer BOB, 
identification of the product with one of the following statements 
indicating the applicable RVP standard in Sec.  1090.215:
    (A) ``9.0 psi CBOB. This product does not meet the requirements for 
summer reformulated gasoline.''
    (B) ``7.8 psi CBOB. This product does not meet the requirements for 
summer reformulated gasoline.''
    (C) ``RBOB. This product meets the requirements for summer 
reformulated or conventional gasoline.''
    (ii) For BOBs designed to produce a finished gasoline that must meet 
an RVP standard required by any SIP approved or promulgated under 42 
U.S.C. 7410 or 7502, additional or substitute language to satisfy the 
state program may be used as necessary but must include at a minimum the 
applicable RVP standard established under the SIP.
    (c) RFG and CG requirements. For batches of RFG and CG, in addition 
to the information required under paragraph (a) of this section, the 
following information must be included on the PTD:
    (1) Summer gasoline language requirements. (i) Except as specified 
in paragraph (c)(1)(ii) of this section, for summer gasoline, 
identification of the product with one of the following statements 
indicating the applicable RVP standard:
    (A) For gasoline that meets the 9.0 psi RVP standard in Sec.  
1090.215(a)(1): ``9.0 psi Gasoline.''
    (B) For gasoline that meets the 7.8 psi RVP standard in Sec.  
1090.215(a)(2): ``7.8 psi Gasoline.''
    (C) For gasoline that meets the RFG 7.4 psi RVP standard in Sec.  
1090.215(a)(3): ``Reformulated Gasoline.''
    (ii) For finished gasoline that meets an RVP standard required by 
any SIP approved or promulgated under 42 U.S.C. 7410 or 7502, additional 
or substitute language to satisfy the state program may be used as 
necessary.
    (2) Ethanol content language requirements. (i) For gasoline-ethanol 
blends, one of the following statements that accurately describes the 
gasoline:
    (A) For gasoline containing no ethanol (``E0''), the following 
statement: ``E0: Contains no ethanol.''
    (B) For finished gasoline containing less than 9 volume percent 
ethanol, the following statement: ``EX--Contains up to X% ethanol.'' The 
term X refers to the maximum volume percent ethanol present in the 
gasoline-ethanol blend.
    (C) For E10, the following statement: ``E10: Contains between 9 and 
10 vol % ethanol.''
    (D) For E15, the following statement: ``E15: Contains between 10 and 
15 vol % ethanol.''
    (E) For gasoline-ethanol blends containing more than 15 volume 
percent ethanol, the following statement: ``EXX: Contains up to XX vol % 
ethanol.'' The term XX refers to the maximum volume percent ethanol 
present in the gasoline-ethanol blend.
    (ii) No person may designate a fuel as E10 if the fuel is produced 
by blending ethanol and gasoline in a manner designed to contain less 
than 9.0 or more than 10.0 volume percent ethanol.
    (iii) No person may designate a fuel as E15 if the fuel is produced 
by blending ethanol and gasoline in a manner designed to contain less 
than 10.0 or more than 15.0 volume percent ethanol.
    (d) Oxygenate language requirements. In addition to any other PTD 
requirements of this subpart, on each occasion when any person transfers 
custody or title to any oxygenate upstream of any oxygenate blending 
facility, the transferor must provide to the transferee PTDs that 
include the following information, as applicable:
    (1) For DFE: ``Denatured fuel ethanol, maximum 10 ppm sulfur.''

[[Page 582]]

    (2) For other oxygenates, the name of the specific oxygenate must be 
identified on the PTD, followed by ``maximum 10 ppm sulfur.'' For 
example, for isobutanol, the following statement on the PTD would be 
required, ``Isobutanol, maximum 10 ppm sulfur.''
    (e) Gasoline detergent language requirements. In addition to any 
other PTD requirements of this subpart, on each occasion when any person 
transfers custody or title to any gasoline detergent, the transferor 
must provide to the transferee PTDs that include the following 
information:
    (1) The identity of the product being transferred as detergent, 
detergent-additized gasoline, or non-additized detergent gasoline.
    (2) The name of the registered detergent must be used to identify 
the detergent additive package on its PTD and the LAC on the PTD must be 
consistent with the requirements in Sec.  1090.260.
    (f) Gasoline additives language requirements. In addition to any 
other PTD requirements of this subpart, on each occasion when any person 
transfers custody or title to any gasoline additive that meets the 
requirements in Sec.  1090.265(a), the transferor must provide to the 
transferee PTDs that include the following information:
    (1) The maximum allowed treatment rate of the additive so that the 
additive will contribute no more than 3 ppm sulfur to the finished 
gasoline.
    (2) [Reserved]
    (g) Certified ethanol denaturant language requirements. In addition 
to any other PTD requirements of this subpart, on each occasion when any 
person transfers custody or title to any certified ethanol denaturant 
that meets the requirements in Sec.  1090.275, the transferor must 
provide to the transferee PTDs that include the following information:
    (1) The following statement: ``Certified Ethanol Denaturant suitable 
for use in the manufacture of denatured fuel ethanol meeting EPA 
standards.''
    (2) The PTD must state that the sulfur content is 330 ppm or less. 
If the certified ethanol denaturant manufacturer represents a batch of 
denaturant as having a maximum sulfur content lower than 330 ppm, the 
PTD must instead state that lower sulfur maximum (e.g., has a sulfur 
content of 120 ppm or less).
    (h) Butane and pentane language requirements. (1) In addition to any 
other PTD requirements of this subpart, on each occasion when any person 
transfers custody or title to any certified butane or certified pentane, 
the transferor must provide to the transferee PTDs that include the 
following information:
    (i) The certified butane or certified pentane producer company name 
and, for the certified pentane producer, the facility registration 
number issued by EPA.
    (ii) One of the following statements, as applicable:
    (A) ``Certified pentane for use by certified pentane blenders.''
    (B) ``Certified butane for use by certified butane blenders.''
    (2) PTDs must be transferred from each party transferring certified 
butane or certified pentane for use by a certified butane or certified 
pentane blender to each party that receives the certified butane or 
certified pentane through to the certified butane or certified pentane 
blender, respectively.
    (i) TGP language requirements. In addition to any other PTD 
requirements of this subpart, on each occasion when any person transfers 
custody or title to any TGP, the transferor must provide to the 
transferee PTDs that include the following information:
    (1) The following statement: ``Transmix Gasoline Product--not for 
use as gasoline.''
    (2) [Reserved]



Sec.  1090.1115  PTD requirements for distillate and residual fuels.

    (a) General requirements. On each occasion when any person transfers 
custody or title of any distillate or residual fuel, other than when 
fuel is sold or dispensed to the ultimate end user at a retail outlet or 
WPC facility, the transferor must provide the transferee PTDs that 
include the following information:
    (1) The sulfur per-gallon standard that the transferor represents 
the fuel to meet under subpart D of this part (e.g., 15 ppm sulfur for 
ULSD or 1,000 ppm sulfur for ECA marine fuel).

[[Page 583]]

    (2) An accurate and clear statement of the applicable designation(s) 
of the fuel under Sec.  1090.1015 (e.g., ``ULSD'', ``500 ppm LM diesel 
fuel'', or ``ECA marine fuel'').
    (3) If the fuel does not meet the sulfur standard in Sec.  
1090.305(b) for ULSD, the following statement: ``Not for use in highway 
vehicles or engines or nonroad, locomotive, or marine engines.''
    (b) 500 ppm LM diesel fuel language requirements. For batches of 500 
ppm LM diesel fuel, in addition to the information required under 
paragraph (a) of this section, PTDs must include the following 
information:
    (1) The following statement: ``500 ppm sulfur (maximum) LM diesel 
fuel. For use only in accordance with a compliance plan under 40 CFR 
1090.515(g). Not for use in highway vehicles or other nonroad vehicles 
and engines.''
    (2) [Reserved]
    (c) ECA marine fuel language requirements. For batches of ECA marine 
fuel, in addition to the information required under paragraph (a) of 
this section, PTDs must include the following information:
    (1) The following statement: ``1,000 ppm sulfur (maximum) ECA marine 
fuel. For use in Category 3 marine vessels only. Not for use in Category 
1 or Category 2 marine vessels.''
    (2) A party may replace the required statement in paragraph (c)(1) 
of this section with the following statement for qualifying vessels 
under 40 CFR part 1043: ``High sulfur fuel. For use only in ships as 
allowed by MARPOL Annex VI, Regulation 3 or Regulation 4.''
    (3) Under 40 CFR 1043.80, a fuel supplier (i.e., the person who 
transfers custody or title of marine fuel onto a vessel) must provide 
bunker delivery notes to vessel operators.
    (d) Distillate global marine fuel language requirements. For batches 
of distillate global marine fuel, in addition to the information 
required under paragraph (a) of this section, PTDs must include the 
following information:
    (1) The following statement: ``5,000 ppm sulfur (maximum) Distillate 
Global Marine Fuel. For use only in steamships or Category 3 marine 
vessels outside of an Emission Control Area (ECA), consistent with 
MARPOL Annex VI.''
    (2) [Reserved]



Sec.  1090.1120  PTD requirements for diesel fuel additives.

    In addition to any other PTD requirements in this subpart, on each 
occasion when any person transfers custody or title to a diesel fuel 
additive that is subject to the provisions of Sec.  1090.310 to a party 
in the additive distribution system or in the diesel fuel distribution 
system for use downstream of the diesel fuel manufacturing facility, the 
transferor must provide to the transferee PTDs that include the 
following information:
    (a) For diesel fuel additives that comply with the sulfur standard 
in Sec.  1090.310(a), the following statement: ``The sulfur content of 
this diesel fuel additive does not exceed 15 ppm.''
    (b) For diesel fuel additives that meet the requirements in Sec.  
1090.310(b), the transferor must provide to the transferee PTDs that 
identify the additive as such, and comply with all the following:
    (1) Indicate the high sulfur potential of the diesel fuel additive 
by including the following statement: ``This diesel fuel additive may 
exceed the federal 15 ppm sulfur standard. Improper use of this additive 
may result in non-compliant diesel fuel.''
    (2) If the diesel fuel additive package contains a static dissipater 
additive or red dye having a sulfur content greater than 15 ppm, one of 
the following statements must be included that accurately describes the 
contents of the additive package:
    (i) ``This diesel fuel additive contains a static dissipater 
additive having a sulfur content greater than 15 ppm.''
    (ii) ``This diesel fuel additive contains red dye having a sulfur 
content greater than 15 ppm.''
    (iii) ``This diesel fuel additive contains a static dissipater 
additive and red dye having a sulfur content greater than 15 ppm.''
    (3) Include the following information:
    (i) The diesel fuel additive package's maximum sulfur concentration.

[[Page 584]]

    (ii) The maximum recommended concentration for use of the diesel 
fuel additive package in diesel fuel, in volume percent.
    (iii) The contribution to the sulfur content of the fuel (in ppm) 
that would result if the diesel fuel additive package is used at the 
maximum recommended concentration.
    (c) For diesel fuel additives that are sold in containers for use by 
the ultimate consumer of diesel fuel, each transferor must display on 
the additive container, in a legible and conspicuous manner, one of the 
following statements, as applicable:
    (1) For diesel fuel additives that comply with the sulfur standard 
in Sec.  1090.310(a): ``This diesel fuel additive complies with the 
federal low sulfur content requirements for use in diesel motor vehicles 
and nonroad engines.''
    (2) For diesel fuel additives that do not comply with the sulfur 
standard in Sec.  1090.310(a), the following statement: ``This diesel 
fuel additive does not comply with federal ultra-low sulfur content 
requirements.''



Sec.  1090.1125  Alternative PTD language.

    (a) Alternative PTD language to the language specified in this 
subpart may be used if approved by EPA in advance. Such language must 
contain all the applicable informational elements specified in this 
subpart.
    (b) Requests for alternative PTD language must be submitted as 
specified in Sec.  1090.10.



                         Subpart M_Recordkeeping



Sec.  1090.1200  General recordkeeping requirements.

    (a) Length of time records must be kept. Records required under this 
part must be kept for 5 years from the date they were created, except 
that records relating to credit transfers must be kept by the transferor 
for 5 years from the date the credits were transferred and must be kept 
by the transferee for 5 years from the date the credits were 
transferred, used, or terminated, whichever is later.
    (b) Make records available to EPA. On request by EPA, the records 
specified in this part must be provided to EPA. For records that are 
electronically generated or maintained, the equipment and software 
necessary to read the records must be made available or, upon approval 
by EPA, electronic records must be converted to paper documents that 
must be provided to EPA.



Sec.  1090.1205  Recordkeeping requirements for all regulated parties.

    (a) Overview. Any party subject to the requirements and provisions 
of this part must keep records containing the information specified in 
this section.
    (b) PTDs. Any party that transfers custody or title of any fuel, 
fuel additive, or regulated blendstock must maintain the PTDs for which 
the party is the transferor or transferee.
    (c) Sampling and testing. Any party that performs any sampling and 
testing on any fuel, fuel additive, or regulated blendstock must keep 
records of the following information:
    (1) The location, date, time, and storage tank or truck, rail car, 
or vessel identification for each sample collected.
    (2) The identification of the person(s) who collected the sample and 
the person(s) who performed the testing.
    (3) The results of all tests as originally printed by the testing 
apparatus, or where no printed result is produced, the results as 
originally recorded by the person or apparatus that performed the test. 
Where more than one test is performed, all the results must be retained.
    (4) The methodology used for any testing under this part.
    (5) Records related to performance-based measurement and statistical 
quality control under Sec. Sec.  1090.1360 through 1090.1375.
    (6) Records related to gasoline deposit control testing under Sec.  
1090.1395.
    (7) Records demonstrating the actions taken to stop the sale of any 
fuel, fuel additive, or regulated blendstock that is found not to be in 
compliance with applicable standards under this part, and the actions 
taken to identify the cause of any noncompliance and prevent future 
instances of noncompliance.
    (d) Registration. Any party required to register under subpart I of 
this part must maintain records supporting the

[[Page 585]]

information required to complete and maintain the registration for the 
party's company and each registered facility. The party must also 
maintain copies of any confirmation received from the submission of such 
registration information to EPA.
    (e) Reporting. Any party required to submit reports under subpart J 
of this part must maintain copies of all reports submitted to EPA. The 
party must also maintain copies of any confirmation received from the 
submission of such reports to EPA.
    (f) Exemptions. Any party that produces or distributes exempt fuel, 
fuel additive, or regulated blendstock under subpart G of this part must 
keep the following records:
    (1) Records demonstrating the designation of the fuel, fuel 
additive, or regulated blendstock under subparts G and K of this part.
    (2) Copies of PTDs generated or accompanying the exempt fuel, fuel 
additive, or regulated blendstock.
    (3) Records demonstrating that the exempt fuel, fuel additive, or 
regulated blendstock was actually used in accordance with the 
requirements of the applicable exemption(s) under subpart G of this 
part.



Sec.  1090.1210  Recordkeeping requirements for gasoline manufacturers.

    (a) Overview. In addition to the requirements in Sec.  1090.1205, a 
gasoline manufacturer must keep records for each of their facilities 
that include the information in this section.
    (b) Batch records. For each batch of gasoline, a gasoline 
manufacturer must keep records of the following information:
    (1) The results of tests, including any calculations necessary to 
transcribe or correlate test results into reported values under subpart 
J of this part, performed to determine gasoline properties and 
characteristics as specified in subpart N of this part.
    (2) The batch volume.
    (3) The batch number.
    (4) The date the batch was produced or imported.
    (5) The designation of the batch under Sec.  1090.1010.
    (6) The PTDs for any gasoline produced or imported.
    (7) The PTDs for any gasoline received.
    (c) Downstream oxygenate accounting. For BOB for which the gasoline 
manufacturer has accounted for oxygenate added downstream under Sec.  
1090.710, a gasoline manufacturer must keep records of the following 
information:
    (1) The test results for hand blends prepared under Sec.  1090.1340.
    (2) Records that demonstrate that the gasoline manufacturer 
participates in the NFSP under Sec.  1090.1405.
    (3) Records that demonstrate that the gasoline manufacturer 
participates in the NSTOP under Sec.  1090.1450.
    (4) Compliance calculations specified in Sec.  1090.700 based on an 
assumed addition of oxygenate.
    (d) PCG and TGP. For new batches of gasoline produced by adding 
blendstock to PCG or TGP, a gasoline manufacturer must keep records of 
the following information:
    (1) Records that reflect the storage and movement of the PCG or TGP 
and blendstock within the fuel manufacturing facility to the point such 
PCG or TGP is used to produce gasoline or BOB.
    (2) For new batches of gasoline produced by adding blendstock to PCG 
or TGP under Sec.  1090.1320(a)(1) or Sec.  1090.1325, respectively, 
keep records of the following additional information:
    (i) The results of tests to determine the sulfur content, benzene 
content, oxygenate(s) content, and in the summer, RVP, for the PCG or 
TGP and volume of the PCG or TGP when received at the fuel manufacturing 
facility.
    (ii) Records demonstrating which specific batches of PCG or TGP were 
used in each new batch of gasoline.
    (iii) Records demonstrating which blendstocks were used in each new 
batch of gasoline.
    (iv) Records of the test results for sulfur content, benzene 
content, oxygenate(s) content, distillation parameters, and in the 
summer, RVP, for each new batch of gasoline.
    (3) For new batches of gasoline produced by adding blendstock to PCG 
or TGP under Sec.  1090.1320(a)(2), keep records of the following 
additional information:

[[Page 586]]

    (i) Records of the test results for sulfur content, benzene content, 
oxygenate(s) content, and in the summer, RVP, of each blendstock used to 
produce the new batch of gasoline.
    (ii) Records of the test results for sulfur content and in the 
summer, RVP, of each new batch of gasoline.
    (iii) Records demonstrating which blendstocks were used in each new 
batch of gasoline.
    (e) Certified butane and certified pentane blenders. For certified 
butane or certified pentane blended into gasoline or BOB under Sec.  
1090.1320, a certified butane or certified pentane blender must keep 
records of the following information:
    (1) The volume of certified butane or certified pentane added.
    (2) The purity and properties of the certified butane or certified 
pentane specified in Sec.  1090.250 or Sec.  1090.255, respectively.
    (f) Importation of gasoline treated as blendstock. For any imported 
GTAB, an importer must keep records of documents that reflect the 
storage and physical movement of the GTAB from the point of importation 
to the point of blending to produce gasoline or the point at which the 
GTAB was certified as gasoline.
    (g) ABT. A gasoline manufacturer must keep records of the following 
information related to their ABT activities under subpart H of this 
part, as applicable:
    (1) Compliance sulfur values and compliance benzene values under 
Sec.  1090.700, and the calculations used to determine those values.
    (2) The number of valid credits in possession of the gasoline 
manufacturer at the beginning of each compliance period, separately by 
facility and compliance period of generation.
    (3) The number of credits generated by the gasoline manufacturer 
under Sec.  1090.725, separately by facility and compliance period of 
generation.
    (4) If any credits were obtained from or transferred to other 
parties, all the following for each other party:
    (i) The party's name.
    (ii) The party's EPA company registration numbers.
    (iii) The number of credits obtained from or transferred to the 
party.
    (5) The number of credits that expired at the end of each compliance 
period, separately by facility and compliance period of generation.
    (6) The number of credits that will be carried over into the next 
compliance period, separately by facility and compliance period of 
generation.
    (7) The number of credits used, separately by facility and 
compliance period of generation.
    (8) Contracts or other commercial documents that establish each 
transfer of credits from the transferor to the transferee.
    (9) Documentation that supports the number of credits transferred 
between facilities within the same company (i.e., intracompany 
transfers).



Sec.  1090.1215  Recordkeeping requirements for diesel fuel, 
ECA marine fuel, and distillate global marine fuel manufacturers.

    (a) Overview. In addition to the requirements in Sec.  1090.1205, a 
diesel fuel or ECA marine fuel manufacturer must keep records for each 
of their facilities that include the information in this section.
    (b) Batch records. For each batch of ULSD, 500 ppm LM diesel fuel, 
or ECA marine fuel, a diesel fuel or ECA marine fuel manufacturer must 
keep records of the following information:
    (1) The batch volume.
    (2) The batch number.
    (3) The date the batch was produced or imported.
    (4) The designation of the batch under Sec.  1090.1015.
    (5) All documents and information created or used for the purpose of 
batch designation under Sec.  1090.1015, including PTDs for the batch.
    (c) Distillate global marine fuel manufacturers. For distillate 
global marine fuel, a distillate global marine fuel manufacturer must 
keep records of the following information:
    (1) The designation of the fuel as distillate global marine fuel.
    (2) The PTD for the distillate global marine fuel.



Sec.  1090.1220  Recordkeeping requirements for oxygenate blenders.

    (a) Overview. In addition to the requirements in Sec.  1090.1205, an 
oxygenate

[[Page 587]]

blender that blends oxygenate into gasoline must keep records that 
include the information in this section.
    (b) Oxygenate blenders. For each occasion that an oxygenate blender 
blends oxygenate into gasoline, the oxygenate blender must keep records 
of the following information:
    (1) The date, time, location, and identification of the blending 
tank or truck in which the blending occurred.
    (2) The volume and oxygenate requirement of the gasoline to which 
oxygenate was added.
    (3) The volume, type, and purity of the oxygenate that was added, 
and documents that show the supplier(s) of the oxygenate used.



Sec.  1090.1225  Recordkeeping requirements for gasoline additives.

    (a) Gasoline additive manufacturers. In addition to the requirements 
in Sec.  1090.1205, a gasoline additive manufacturer must keep records 
of the following information for each batch of additive produced or 
imported:
    (1) The batch volume.
    (2) The date the batch was produced or imported.
    (3) The PTD for the batch.
    (4) The maximum recommended treatment rate.
    (5) The gasoline additive manufacturer's control practices that 
demonstrate that the additive will contribute no more than 3 ppm on a 
per-gallon basis to the sulfur content of gasoline when used at the 
maximum recommended treatment rate.
    (b) Parties that take custody of gasoline additives. Except for 
gasoline additives packaged for addition to gasoline in the vehicle fuel 
tank, all parties that take custody of gasoline additives for bulk 
addition to gasoline--from the producer through to the gasoline additive 
blender that adds the additive to gasoline--must keep records of the 
following information:
    (1) The PTD for each batch of gasoline additive.
    (2) The treatment rate at which the additive was added to gasoline, 
as applicable.
    (3) The volume of gasoline that was treated with the additive, as 
applicable. A new record must be initiated in each case where a new 
batch of additive is mixed into a storage tank from which the additive 
is drawn to be injected into gasoline.



Sec.  1090.1230  Recordkeeping requirements for oxygenate producers.

    (a) Oxygenate producers. In addition to the requirements in Sec.  
1090.1205, an oxygenate producer must keep records of the following 
information for each batch of oxygenate:
    (1) The batch volume.
    (2) The batch number.
    (3) The date the batch was produced or imported.
    (4) The PTD for the batch.
    (5) The sulfur content of the batch.
    (6) The sampling and testing records specified in Sec.  
1090.1205(c), if the sulfur content of the batch was determined by 
analytical testing.
    (b) DFE producers. In addition to the requirements of paragraph (a) 
of this section, a DFE producer must keep records of the following 
information for each batch of DFE if the sulfur content of the batch was 
determined under Sec.  1090.1330:
    (1) The name and title of the person who calculated the sulfur 
content of the batch.
    (2) The date the calculation was performed.
    (3) The calculated sulfur content.
    (4) The sulfur content of the neat (un-denatured) ethanol.
    (5) The date each batch of neat ethanol was produced.
    (6) The neat ethanol batch number.
    (7) The neat ethanol batch volume.
    (8) As applicable, the neat ethanol production quality control 
records, or the test results on the neat ethanol, including all the 
following:
    (i) The location, date, time, and storage tank or truck 
identification for each sample collected.
    (ii) The name and title of the person who collected the sample and 
the person who performed the test.
    (iii) The results of the test as originally printed by the testing 
apparatus, or where no printed result is produced, the results as 
originally recorded by the person who performed the test.
    (iv) Any record that contains a test result for the sample that is 
not identical to the result recorded in paragraph (b)(8)(iii) of this 
section.

[[Page 588]]

    (v) The test methodology used.
    (9) The sulfur content of each batch of denaturant used, and the 
volume percent at which the denaturant was added to neat (un-denatured) 
ethanol to produce DFE.
    (10) The PTD for each batch of denaturant used.
    (c) Parties that take custody of oxygenate. All parties that take 
custody of oxygenate--from the oxygenate producer through to the 
oxygenate blender--must keep records of the following information:
    (1) The PTD for each batch of oxygenate.
    (2) [Reserved]



Sec.  1090.1235  Recordkeeping requirements for ethanol denaturant.

    (a) Certified ethanol denaturant producers. In addition to the 
requirements in Sec.  1090.1205, a certified ethanol denaturant producer 
must keep records of the following information for each batch of 
certified ethanol denaturant:
    (1) The batch volume.
    (2) The batch number.
    (3) The date the batch was produced or imported.
    (4) The PTD for the batch.
    (5) The sulfur content of the batch.
    (b) Parties that take custody of ethanol denaturants. All parties 
that take custody of denaturant designated as suitable for use in the 
production of DFE under Sec.  1090.270(b) must keep records of the 
following information:
    (1) The PTD for each batch of denaturant.
    (2) The volume percent at which the denaturant was added to ethanol, 
as applicable.



Sec.  1090.1240  Recordkeeping requirements for gasoline detergent blenders.

    (a) Overview. In addition to the requirements in Sec.  1090.1205, a 
gasoline detergent blender must keep records that include the 
information in this section.
    (b) Gasoline detergent blenders. A gasoline detergent blender must 
keep records of the following information:
    (1) The PTD for each detergent used.
    (2) For an automated detergent blending facility, the following 
information:
    (i) The dates of the VAR Period.
    (ii) The total volume of detergent blended into gasoline, as 
determined using one of the following methods, as applicable:
    (A) For a facility that uses in-line meters to measure the amount of 
detergent blended, the total volume of detergent measured, together with 
supporting data that includes one of the following:
    (1) The beginning and ending meter readings for each meter being 
measured.
    (2) Other comparable metered measurements.
    (B) For a facility that uses a gauge to measure the inventory of the 
detergent storage tank, the total volume of detergent must be calculated 
as follows:

VD = DIi - DIf + DIa - DIw

Where:

VD = Volume of detergent.
DIi = Initial detergent inventory of the tank.
DIf = Final detergent inventory of the tank.
DIa = Sum of any additions to detergent inventory.
DIw = Sum of any withdrawals from detergent inventory for 
          purposes other than the additization of gasoline.

    (C) The value of each variable in the equation in paragraph 
(b)(2)(ii)(B) of this section must be separately recorded. Recorded 
volumes of detergent must be expressed to the nearest gallon (or smaller 
units), except that detergent volumes of five gallons or less must be 
expressed to the nearest tenth of a gallon (or smaller units). However, 
if the blender's equipment is unable to accurately measure to the 
nearest tenth of a gallon, then such volumes must be rounded downward to 
the next lower gallon.
    (iii) The total volume of gasoline to which detergent has been 
added, together with supporting data that includes one of the following:
    (A) The beginning and ending meter measurements for each meter being 
measured.
    (B) The metered batch volume measurements for each meter being 
measured.
    (C) Other comparable metered measurements.
    (iv) The actual detergent concentration, calculated as the total 
volume of detergent added (as determined under

[[Page 589]]

paragraph (b)(2)(ii) of this section) divided by the total volume of 
gasoline (as determined under paragraph (b)(2)(iii) of this section). 
The concentration must be calculated and recorded to four digits and 
rounded as specified in Sec.  1090.50.
    (v) The initial detergent concentration rate, together with the date 
and description of each adjustment to any initially set concentration.
    (vi) If the detergent injector is set below the applicable LAC, or 
adjusted by more than 10 percent above the concentration initially set 
in the VAR Period, documentation establishing that the purpose of the 
change is to correct a batch misadditization prior to the end of the VAR 
Period and prior to the transfer of the batch to another party or to 
correct an equipment malfunction and the date and adjustments of the 
correction.
    (vii) Documentation reflecting the performance and results of the 
calibration of detergent equipment under Sec.  1090.1390.
    (3) For a non-automated detergent blending facility, keep records of 
the following information:
    (i) The date of additization.
    (ii) The volume of detergent added.
    (iii) The volume of gasoline to which the detergent was added.
    (iv) The actual detergent concentration, calculated as the volume of 
detergent added (per paragraph (b)(3)(ii) of this section) divided by 
the volume of gasoline (per paragraph (b)(3)(iii) of this section). The 
concentration must be calculated and recorded to four digits and rounded 
as specified in Sec.  1090.50.



Sec.  1090.1245  Recordkeeping requirements for independent surveyors.

    (a) Overview. In addition to the requirements in Sec.  1090.1205, an 
independent surveyor must keep records that include the information in 
this section.
    (b) Independent surveyors. An independent surveyor must keep records 
of the following information, as applicable:
    (1) Records related to the NFSP under Sec.  1090.1405.
    (2) Records related to a geographically-focused E15 survey program 
under Sec.  1090.1420(b).
    (3) Records related to the NSTOP under Sec.  1090.1450.



Sec.  1090.1250  Recordkeeping requirements for auditors.

    (a) Overview. In addition to the requirements in Sec.  1090.1205, an 
auditor must keep records that include the information in this section.
    (b) Auditors. An auditor must keep records of the following 
information:
    (1) Documents pertaining to the performance of each audit performed 
under subpart S of this part, including all correspondence between the 
auditor and the fuel manufacturer.
    (2) Copies of each attestation report prepared and all related 
records developed to prepare the attestation report.



Sec.  1090.1255  Recordkeeping requirements for transmix processors,
transmix blenders, transmix distributors, and pipeline operators.

    (a) Overview. In addition to the requirements in Sec.  1090.1205, a 
transmix processor, transmix blender, transmix distributor, or pipeline 
operator must keep records that include the information in this section.
    (b) Transmix. (1) A transmix processor or transmix distributor must 
keep records that reflect the results of any sampling and testing 
required under subpart F or M of this part.
    (2) A transmix processor must keep records showing the volumes of 
TGP recovered from transmix and the type and amount of any blendstock or 
PCG added to make gasoline from TGP under Sec.  1090.505.
    (3) A transmix processor that adds blendstock to TGP or PCG must 
keep records under Sec.  1090.1210(d).
    (4) A transmix blender must keep records showing compliance with the 
quality assurance program and/or sampling and testing requirements in 
Sec.  1090.500, and for each batch of gasoline with which transmix is 
blended, the volume of the batch, and the volume of transmix blended 
into the batch.
    (c) 500 ppm LM diesel fuel. A manufacturer or distributor of 500 ppm 
LM diesel fuel using transmix must keep records of the following 
information, as applicable:
    (1) Copies of the compliance plan required under Sec.  1090.515(g).

[[Page 590]]

    (2) Documents demonstrating how the party complies with each 
applicable element of the compliance plan under Sec.  1090.515(g).
    (3) Documents and copies of calculations used to determine 
compliance with the 500 ppm LM diesel fuel volume requirements under 
Sec.  1090.515(c).
    (4) Documents or information that demonstrates that the 500 ppm LM 
diesel fuel was only used in locomotive and marine engines that are not 
required to use ULSD under 40 CFR 1033.815 and 40 CFR 1042.660, 
respectively.
    (d) Pipeline operators. A pipeline operator must keep records that 
demonstrate compliance with the interface handling practices in Sec.  
1090.520.



               Subpart N_Sampling, Testing, and Retention



Sec.  1090.1300  General provisions.

    (a) This subpart is organized as follows:
    (1) Sections 1090.1310 through 1090.1330 specify the scope of 
required testing, including special provisions that apply in several 
unique circumstances.
    (2) Sections 1090.1335 through 1090.1345 specify handling procedures 
for collecting and retaining samples. Sections 1090.1350 through 
1090.1375 specify the procedures for measuring the specified parameters. 
These procedures apply to anyone who performs testing under this 
subpart.
    (3) Section 1090.1390 specifies the requirements for calibrating 
automated detergent blending equipment.
    (4) Section 1090.1395 specifies the procedures for testing related 
to gasoline deposit control test procedure.
    (b) If you need to meet requirements for a quality assurance program 
at a minimum frequency, your first batch of product triggers the testing 
requirement. The specified frequency serves as a deadline for performing 
the required testing, and as a starting point for the next testing 
period. The following examples illustrate the requirements for testing 
based on sampling the more frequent of every 90 days or 500,000 gallons 
of certified butane you received from a supplier:
    (1) If your testing period starts on March 1 and you use less than 
500,000 gallons of butane from March 1 through May 29 (90 days), you 
must perform testing under a quality assurance program sometime between 
March 1 and May 29. Your next test period starts with the use of butane 
on May 30 and again ends after 90 days or after you use 500,000 gallons 
of butane, whichever occurs first.
    (2) If your testing period starts on March 1 and you use 500,000 
gallons of butane for the testing period on April 29 (60 days), you must 
perform testing under a quality assurance program sometime between March 
1 and April 29. Your next testing period starts with the use of butane 
on April 30 and again ends after 90 days or after you use 500,000 
gallons of butane, whichever occurs first.
    (c) Anyone acting on behalf of a regulated party to demonstrate 
compliance with requirements under this part must meet the requirements 
of this subpart in the same way that the party needs to meet those 
requirements for its own testing. The regulated party and the third 
party will both be liable for any violations arising from the third 
party's failure to meet the requirements of this subpart.
    (d) Anyone performing tests under this subpart must apply good 
laboratory practices for all sampling, measurement, and calculations 
related to testing required under this part. This requires performing 
these procedures in a way that is consistent with generally accepted 
scientific and engineering principles and properly accounting for all 
available relevant information.
    (e) Subpart Q of this part has provisions related to importation, 
including additional provisions that specify how to meet the sampling 
and testing requirements of this subpart.

                            Scope of Testing



Sec.  1090.1310  Testing to demonstrate compliance with standards.

    (a) Perform testing as needed to certify fuel, fuel additive, or 
regulated blendstock as specified in subpart K of this part. This 
section specifies additional test requirements.

[[Page 591]]

    (b) A fuel manufacturer, fuel additive manufacturer, or regulated 
blendstock producer must perform the following measurements before fuel, 
fuel additive, or regulated blendstock from a given batch leaves the 
facility, except as specified in Sec.  1090.1315:
    (1) Diesel fuel. Perform testing for each batch of ULSD, 500 ppm LM 
diesel fuel, and ECA marine fuel to demonstrate compliance with sulfur 
standards.
    (2) Gasoline. Perform testing for each batch of gasoline to 
demonstrate compliance with sulfur standards and perform testing for 
each batch of summer gasoline to demonstrate compliance with RVP 
standards.
    (c) The following testing provisions apply for gasoline, oxygenate, 
certified ethanol denaturant, certified butane, and certified pentane:
    (1) A gasoline manufacturer producing BOB for which oxygenate added 
downstream is accounted for under Sec.  1090.710 must prepare a hand 
blend as specified in Sec.  1090.1340 and perform the following 
measurements:
    (i) Measure the sulfur content of both the BOB and the hand blend.
    (ii) Except as specified in Sec.  1090.1325(c), measure the benzene 
content of the hand blend.
    (iii) For Summer CG, measure the RVP of the BOB.
    (iv) For Summer RFG, measure the RVP of the hand blend.
    (2) A gasoline manufacturer producing gasoline for which oxygenate 
added downstream is not accounted for under Sec.  1090.710 (e.g., E0 or 
so-called suboctane gasoline) must perform the following measurements:
    (i) Measure the sulfur content of the gasoline.
    (ii) Except as specified in Sec.  1090.1325(c), measure the benzene 
content of the gasoline.
    (iii) For Summer CG and Summer RFG, measure the RVP of the gasoline.
    (iv) For Summer RFG that is designated as ``Intended for Oxygenate 
Blending'' under Sec.  1090.1010(a)(4), create a hand blend as specified 
in Sec.  1090.1340 and measure the RVP of the hand blend.
    (v) For gasoline blended with oxygenate, measure the oxygenate 
content of the gasoline.
    (3) An oxygenate producer must measure the sulfur content of each 
batch of oxygenate, except that a DFE producer may meet the alternative 
requirements in Sec.  1090.1330.
    (4) An ethanol denaturant producer that certifies denaturant under 
Sec.  1090.1330 must measure the sulfur content of each batch of 
denaturant.
    (5) A certified butane or certified pentane producer must perform 
sampling and testing to demonstrate compliance with purity 
specifications and sulfur and benzene standards as specified in Sec.  
1090.1320.
    (6) A transmix processor producing gasoline from TGP must test each 
batch of gasoline for parameters required to demonstrate compliance with 
Sec.  1090.505 as specified in Sec.  1090.1325.
    (d) A blending manufacturer producing gasoline by adding blendstock 
to PCG must comply with Sec.  1090.1320.
    (e) For gasoline produced at a fuel blending facility or a transmix 
processing facility, a gasoline manufacturer must measure such gasoline 
for oxygenate and for distillation parameters (i.e., T10, T50, T90, 
final boiling point, and percent residue). However, a fuel manufacturer 
or transmix processor does not need to measure the oxygenate content of 
gasoline if PCG, transmix, TGP, and blendstocks used to produce the 
batch did not contain any oxygenates, based on the following 
documentation:
    (1) For PCG, documentation consists of oxygenate content identified 
on PTDs.
    (2) For transmix, TGP, and blendstocks, documentation consists of 
affidavits or oxygenate test results from the person providing the 
transmix or blendstock stating that these products do not contain 
oxygenate.



Sec.  1090.1315  In-line blending.

    A fuel manufacturer using in-line blending equipment may qualify for 
a waiver from the requirement in Sec.  1090.1310(b) to test every batch 
of fuel before the fuel leaves the fuel manufacturing facility as 
follows:
    (a) Submit a request signed by the RCO to EPA with the following 
information:
    (1) Describe the location of your in-line blending operation, how 
long it

[[Page 592]]

has been in operation, and how much of each type and grade of fuel you 
have blended over the preceding 3 years (or since starting the in-line 
blending operation if it is less than 3 years). Describe the physical 
layout of the blending operation and how you move the blended fuel into 
distribution. Also describe how your automated system monitors and 
controls blending proportions and the properties of the blended fuel. 
For new installations, describe these as a planned operation with 
projected volumes by type and grade. Describe clearly which portions of 
your blending operation are the subject of your waiver request.
    (2) Describe how you collect and test composite fuel samples in a 
way that is equivalent to measuring the fuel properties of a batch of 
blended fuel as specified in this subpart. Also describe how your 
procedures conform to the sampling specifications in ASTM D4177 and the 
composite calculations in ASTM D5854 (both incorporated by reference in 
Sec.  1090.95).
    (3) Describe any expectation or plan for you or another party to 
perform additional downstream testing for the same fuel parameters.
    (4) Describe your quality assurance procedures. Explain how you will 
ensure that all fuel will meet all applicable per-gallon standards. 
Describe any experiences from the previous 3 years where these quality 
assurance procedures led you to make corrections to your in-line 
blending operation. Describe how you will deal with release of fuel that 
fails to meet a per-gallon standard.
    (5) Describe any times from the previous 3 years that you modified 
fuel after it left your facility. Describe how you modified the fuel and 
why that was necessary.
    (6) Describe how you will meet the auditing requirements specified 
in Sec.  1090.1850 and any additional, facility-specific considerations 
that relate to those auditing requirements.
    (b) You must arrange for an audit of your blending operation each 
calendar year as specified in Sec.  1090.1850. The audit must review 
procedures and documents to determine whether measured and calculated 
values properly represent the aggregate fuel properties for the blended 
fuel.
    (c) You must submit an updated in-line blending waiver request to 
EPA 60 days before making any material change to your in-line blending 
process. Examples of material changes include changing analyzer hardware 
or programming, changing the location of the analyzer, changing the 
piping configuration, changing the mixing control hardware or 
programming logic, changing sample compositors or compositor settings, 
or expanding fuel blending capacity. Changing the name of the company or 
business unit is an example of a change that is not material.
    (d) If EPA approves your request for a waiver under this section, 
you may need to update your procedures for more effective control and 
documentation of measured fuel parameters based on audit results, 
development of improved practices, or other information.



Sec.  1090.1320  Adding blendstock to PCG.

    The requirements of this section apply for a refiner or blending 
manufacturer that adds blendstock to PCG to produce a new batch of 
gasoline. Paragraph (b) of this section specifies an alternative 
approach for a certified butane or certified pentane blender. Section 
1090.1325 describes additional provisions that apply to a transmix 
processor.
    (a) Sample and test using one of the following methods to exclude 
PCG from the compliance demonstration for sulfur and benzene:
    (1) Compliance by subtraction. (i) Determine the sulfur content, 
benzene content, and oxygenate content of the PCG before blending 
blendstocks to produce a new batch of gasoline as follows:
    (A) Sample and test the sulfur content, benzene content, and 
oxygenate content of each batch of PCG. The blending manufacturer does 
not need to test PCG for oxygenate content if they can demonstrate that 
the PCG does not contain oxygenates as specified in paragraph 
(a)(1)(i)(C) of this section or Sec.  1090.1310(e)(1).
    (B) If the PCG is a BOB, prepare a hand blend under Sec.  1090.1340 
and test

[[Page 593]]

the hand blend for sulfur content and benzene content.
    (C) The blending manufacturer may use the PCG manufacturer's 
certification test results if the PCG was received directly from the PCG 
manufacturer by an in-tank transfer or tank-to-tank transfer within the 
same terminal as long as the results are from the PCG that is being 
transferred.
    (ii) Determine the volume of PCG that was blended with blendstock to 
produce a new batch of gasoline. Report the PCG as a negative batch as 
specified in Sec.  1090.905(c)(3)(i).
    (iii) After adding blendstock to PCG, sample and test the sulfur 
content, benzene content, and for summer gasoline, RVP, of the new batch 
of gasoline.
    (iv) Determine the volume of the new batch of gasoline. Report the 
new batch of gasoline as a positive batch as specified in Sec.  
1090.905(c)(3)(ii).
    (v) Include the PCG batch and the new batch of gasoline in 
compliance calculations as specified in Sec.  1090.700(d)(4)(i).
    (vi) The sample retention requirements in Sec.  1090.1345 apply for 
both the new batch of gasoline and the associated PCG.
    (2) Compliance by addition. (i) Sample and test the sulfur content 
and benzene content of each batch of blendstock used to produce a new 
batch of gasoline from PCG using the procedures in Sec.  1090.1350. The 
homogeneity requirements for gasoline specified in Sec.  1090.1337 apply 
to blendstock and GTAB collected with manual sampling.
    (ii) Determine the volume of each batch of blendstock used to 
produce the new batch of gasoline.
    (iii) Determine the volume of each blended batch of gasoline, and 
measure the sulfur content and for summer gasoline, RVP, for each 
blended batch of gasoline using the procedures specified in Sec.  
1090.1350. Testing the blended batch of gasoline for sulfur content, 
however, is not required if the fuel manufacturer tests the added 
blendstock and determines that both the blendstock and PCG meet the fuel 
manufacturing facility gate sulfur per-gallon standard in Sec.  
1090.205(b).
    (iv) Report each batch of blendstock as specified in Sec.  
1090.905(c)(4).
    (v) Include each batch of blendstock in compliance calculations as 
specified in Sec.  1090.700(d)(4)(ii).
    (vi) The sample retention requirements in Sec.  1090.1345 apply for 
the new batch of gasoline and for each blendstock.
    (b) A certified butane or certified pentane blender that blends 
certified butane or certified pentane into PCG to make a new batch of 
gasoline may comply with the following requirements instead of the 
requirements of paragraph (a) of this section:
    (1) For summer gasoline, measure RVP of the blended fuel. The fuel 
manufacturer may rely on sulfur and benzene test results from the 
certified butane or certified pentane producer. Note that Sec.  
1090.220(e) disallows adding certified butane or certified pentane to 
Summer RFG or Summer RBOB.
    (2) Before blending the certified butane or certified pentane with 
PCG, obtain a copy of the producer's test results indicating that the 
certified butane or certified pentane meets the standards in Sec.  
1090.250 or Sec.  1090.255, respectively.
    (3) The certified pentane blender must enter into a contract with 
the certified pentane producer to verify that the certified pentane 
producer has an adequate quality assurance program to ensure that the 
certified pentane received will not be contaminated in transit.
    (4) The certified butane or certified pentane blender must conduct a 
quality assurance program to demonstrate that the certified butane or 
certified pentane meets the standards specified in Sec.  1090.250 or 
Sec.  1090.255, respectively. The quality assurance program must be 
based on sampling the more frequent of every 90 days or 500,000 gallons 
of certified butane or certified pentane received from each distributor. 
The certified butane or certified pentane blender may rely on a third 
party to perform the testing.
    (c) This paragraph describes provisions that apply in cases where 
PCG is a BOB for which the PCG manufacturer accounted for oxygenate 
added downstream under Sec.  1090.710 and the blending manufacturer 
makes a new batch that

[[Page 594]]

includes less oxygenate than was specified for the BOB by the PCG 
manufacturer. A blending manufacturer in this circumstance does not 
qualify for the small volume blender exemption for BOB recertification 
under Sec.  1090.740(a)(3) and must comply with all the following.
    (1) Calculate and incur sulfur and benzene deficits under the BOB 
recertification provisions in Sec.  1090.740.
    (2) Comply with either the compliance by subtraction requirements of 
paragraph (a)(1) of this section or the compliance by addition 
requirements of paragraph (a)(2) of this section. For compliance by 
subtraction, test the PCG without adding oxygenate (i.e., test the PCG 
``neat''), and report the PCG volume without adjusting for the volume of 
oxygenate that the PCG manufacturer specified under Sec.  1090.740.



Sec.  1090.1325  Adding blendstock or PCG to TGP.

    The following provisions apply to a transmix processor or blending 
manufacturer producing gasoline by adding blendstock or PCG to TGP:
    (a) Determine the volume, sulfur content, and benzene content of 
each blendstock batch used to produce gasoline for reporting and 
compliance calculations by following the sampling and testing 
requirements in Sec.  1090.1320 and treating the TGP used to produce the 
gasoline as PCG.
    (b) Sample and test the gasoline made from TGP and PCG or blendstock 
to demonstrate compliance with the fuel manufacturing facility gate 
sulfur per-gallon standard in Sec.  1090.205(b) and the applicable RVP 
standard in Sec.  1090.215.
    (c) A transmix processor producing gasoline by only adding TGP to 
PCG does not have to measure the benzene content of the finished 
gasoline.



Sec.  1090.1330  Preparing denatured fuel ethanol.

    Instead of measuring every batch, a DFE producer or importer may 
calculate the sulfur content of a batch of DFE as follows:
    (a) Determine the sulfur content of ethanol before adding denaturant 
by measuring it as specified in Sec.  1090.1310 or by estimating it 
based on your production quality control procedures.
    (b) Use the ppm sulfur content of certified ethanol denaturant 
specified on the PTD for the batch. If the sulfur content is specified 
as a range, use the maximum specified value.
    (c) Calculate the weighted sulfur content of the DFE using the 
values determined under paragraphs (a) and (b) of this section.

                     Handling and Preparing Samples



Sec.  1090.1335  Collecting, preparing, and testing samples.

    (a) General provisions. Use good laboratory practice to collect 
samples to represent the batch you are testing. For example, take steps 
to ensure that a batch is always well mixed before sampling. Also, 
always take steps to prevent sample contamination, such as completely 
flushing sampling taps and piping and pre-rinsing sample containers with 
the product being sampled. Follow the procedures in paragraph (b) of 
this section for manual sampling. Follow the procedures paragraph (c) of 
this section for automatic sampling. Additional requirements for 
measuring RVP are specified in paragraph (d) of this section. A 
description of how to determine compliance based on single or multiple 
tests on single or multiple samples is specified in paragraph (e) of 
this section.
    (b) Manual sampling. Perform manual sampling using one of the 
methods specified in ASTM D4057 (incorporated by reference in Sec.  
1090.95) to demonstrate compliance with standards as follows:
    (1) Collect a ``running'' or ``all-levels'' sample from the top of 
the tank. Drawing a sample from a standpipe is acceptable only if it is 
slotted or perforated to ensure that the drawn sample properly 
represents the whole batch of fuel.
    (2)(i) Use tap sampling or spot sampling to collect upper, middle, 
and lower samples if a running or all-levels sample is impractical for a 
given storage configuration. Collect samples that most closely match the 
recommendations in Table 5 of ASTM D4057. Adjust spot sampling for 
partially filled tanks as shown in Table 1 or Table 5 of ASTM D4057, as 
applicable.

[[Page 595]]

    (ii) Spot sampling must not be used for certification testing unless 
the tank contains less than 10 feet of product.
    (3) If the procedures in paragraphs (b)(1) and (2) of this section 
are impractical for a given storage configuration, you may use 
alternative sampling procedures as specified in ASTM D4057. This applies 
primarily for sampling with trucks, railcars, retail stations, and other 
downstream locations.
    (4) Test results with manual sampling are valid only after you 
demonstrate homogeneity as specified in Sec.  1090.1337.
    (5) Except as specified for marine vessels in Sec.  1090.1605, you 
must not do certification testing with a composite sample from manual 
sampling.
    (c) Automatic sampling. (1) For in-line blending waivers under Sec.  
1090.1315, follow all specifications for automatic sampling as specified 
in EPA's approval letter instead of or in addition to the specifications 
in paragraph (c)(2) of this section. Automatic sampling is also 
appropriate for a configuration involving a pipeline filling a tank that 
will be certified as compliant before it leaves the fuel manufacturing 
facility gate.
    (2) Perform automatic sampling as specified in ASTM D4177 
(incorporated by reference in Sec.  1090.95), with the following 
additional specifications:
    (i) Configure the system to ensure a well-mixed stream at the 
sampling point. Align the start and end of sampling with the start and 
end of creating the batch.
    (ii) The default sampling frequency must follow the recommended 
approach of at least 9,604 samples to represent a batch. Less frequent 
sampling is acceptable as long as the interval between samples does not 
exceed 20 seconds throughout the batch.
    (iii) Collect three samples for individual measurements in addition 
to the composite sample. Draw head, middle, and tail samples after 
flowing 15, 50, and 85 percent of the estimated batch volume, 
respectively.
    (iv) EPA may approve a different sampling strategy under an approved 
in-line blending waiver under Sec.  1090.1315 if it is appropriate for a 
given facility or for a small-volume batch.
    (d) Sampling provisions related to measuring RVP of summer gasoline. 
The following additional provisions apply for preparing samples to 
measure RVP of summer gasoline:
    (1) Meet the additional specifications for manual and automatic 
sampling in ASTM D5842 (incorporated by reference in Sec.  1090.95).
    (2) If you measure other fuel parameters for a given sample in 
addition to RVP testing, always measure RVP first.
    (e) Testing to demonstrate compliance with standards. (1) Perform 
testing as specified in this subpart.
    (2) For parameters subject to per-gallon standards, report the 
highest measured value (or the lowest measured value for testing related 
to cetane index or other parameters that are subject to a standard 
representing a minimum value). This applies for repeat tests on a given 
sample and for testing multiple samples (including head, middle, and 
tail samples from automatic sampling). A batch is noncompliant if any 
tested sample does not meet all applicable per-gallon standards.
    (3) In the case of automatic sampling for parameters subject to 
average standards, report the result from the composite sample to 
represent the batch for demonstrating compliance with the average 
standard. For any repeat testing with the composite sample, calculate 
the arithmetic average from all tests to represent the batch.
    (4) In the case of manual sampling for parameters subject to average 
standards, determine the value representing the batch as follows:
    (i) For testing with only a single sample, report that value to 
represent the batch. If there are repeat tests with that sample, report 
the arithmetic average from all tests to represent the sample.
    (ii) For testing with more than one sample, report the arithmetic 
average from all tested samples to represent the batch. If there are 
repeat tests for any sample, calculate the arithmetic average of those 
repeat tests to determine a single value to represent that sample before 
calculating the average value to represent the batch.

[[Page 596]]



Sec.  1090.1337  Demonstrating homogeneity.

    (a) Certification test results corresponding to manual sampling as 
specified in Sec.  1090.1335(b) are valid only if collected samples meet 
the homogeneity specifications in this section, except that the 
homogeneity testing requirement does not apply in the following cases:
    (1) There is only a single sample using the procedure specified in 
Sec.  1090.1335(b)(2).
    (2) Upright cylindrical tanks that have a liquid depth of less than 
10 feet.
    (3) You draw spot or tap samples as specified in paragraph (c) of 
this section, test each sample for every parameter subject to a testing 
requirement, and use the worst-case test result for each parameter for 
purposes of reporting, meeting per-gallon and average standards, and all 
other aspects of compliance.
    (4) Sampling at a downstream location where it is not possible to 
collect separate samples and steps are taken to ensure that the batch is 
well mixed.
    (b)(1) Testing performed to establish homogeneity is not considered 
certification testing, except as specified in paragraph (b)(2) of this 
section.
    (2) Homogeneity testing may be used as certification testing if any 
of the following criteria are met:
    (i) All tested samples meet all applicable per-gallon standards.
    (ii) The testing meets the requirement in Sec.  1090.1335(b)(2)(ii).
    (iii) The testing follows the procedures specified in paragraph 
(a)(3) of this section.
    (c) Use spot sampling as specified in Sec.  1090.1335(b)(2) for 
homogeneity testing. Tap sampling is acceptable if spot sampling is 
impractical for a given facility.
    (d) Demonstrate homogeneity for gasoline using two of the procedures 
specified in this paragraph (d) with each sample. For summer gasoline, 
the homogeneity demonstration must include RVP measurement.
    (1) Measure API gravity using ASTM D287, ASTM D1298, ASTM D4052, or 
ASTM D7777 (incorporated by reference in Sec.  1090.95).
    (2) Measure the sulfur content as specified in Sec.  1090.1360.
    (3) Measure the benzene content as specified Sec.  1090.1360.
    (4) Measure the RVP as specified in Sec.  1090.1360.
    (e) For testing to meet the diesel fuel standards in subpart D of 
this part, demonstrate homogeneity using one of the procedures specified 
in paragraph (d)(1) or (2) of this section.
    (f) Consider the batch to be homogeneous for a given parameter if 
the measured values for all tested samples vary by less than the 
published reproducibility of the test method multiplied by 0.75 (R x 
0.75). If reproducibility is a function of measured values, calculate 
reproducibility using the average value of the measured parameter 
representing all tested samples. Calculate using all meaningful 
significant figures as specified for the test method, even if Sec.  
1090.1350(c) describes a different precision. For cases that do not 
require a homogeneity demonstration under paragraph (a) of this section, 
the lack of homogeneity demonstration does not prevent a quantity of 
fuel, fuel additive, or regulated blendstock from being considered a 
batch for demonstrating compliance with the requirements of this part.



Sec.  1090.1340  Preparing a hand blend from BOB.

    (a) If you produce or import BOB and instruct downstream blenders to 
add oxygenate, you must meet the requirements of this subpart by 
blending oxygenate that reflects the anticipated sulfur content and 
benzene content of the oxygenate for blending into a BOB sample. To do 
this, prepare each hand blend by adding oxygenate to the BOB sample in a 
way that corresponds to your instructions to downstream blenders for the 
sampled batch of fuel. Prepare a hand blend as follows:
    (1) Take steps to avoid introducing high or low bias in sulfur 
content when selecting from available samples to prepare the hand blend. 
For example, if there are three samples with discrete sulfur 
measurements, select the sample with the mid-range sulfur content. In 
other cases, randomly select the sample.
    (2) If your instructions allow for a downstream blender to add more 
than

[[Page 597]]

one type or concentration of oxygenate, prepare the hand blend as 
follows:
    (i) For summer gasoline intended for blending with ethanol, use the 
lowest specified ethanol blend.
    (ii) For all winter gasoline and for summer gasoline intended for 
blending only with oxygenate other than ethanol, use the lowest 
specified oxygenate concentration, regardless of the type of oxygenate.
    (iii) As an example, if you give instructions for a given batch of 
BOB to perform downstream blending to make E10, E15, and an 8 percent 
blend with butanol, prepare a hand blend for testing winter gasoline 
with 8 percent butanol, and prepare an E10 hand blend for testing summer 
gasoline.
    (b) Prepare the hand blend using the procedures specified in ASTM 
D7717 (incorporated by reference in Sec.  1090.95). The hand blend must 
have an amount of oxygenate that does not exceed the oxygenate 
concentration specified on the PTD for the BOB under Sec.  
1090.1110(b)(1).



Sec.  1090.1345  Retaining samples.

    (a) Retain samples as follows:
    (1) A fuel manufacturer, regulated blendstock producer, or 
independent surveyor must keep representative samples of gasoline, 
diesel fuel, or oxygenate that is subject to certification testing 
requirements under this subpart for at least 30 days after testing is 
complete, except that a longer sample retention of 90 days applies for a 
blending manufacturer that produces gasoline.
    (2) A certified pentane producer must keep representative samples of 
certified pentane for at least 30 days after testing is complete.
    (3) A blending manufacturer required to test blendstock under Sec.  
1090.1320(a)(2) must keep representative samples of the blendstock and 
the new batch of gasoline for at least 90 days after testing is 
complete.
    (4) An oxygenate producer or importer must keep oxygenate samples as 
follows:
    (i) Keep a representative sample of any tested oxygenate. Also keep 
a representative sample of DFE if you used the provisions of Sec.  
1090.1330 to calculate its sulfur content.
    (ii) Keep all the samples you collect over the previous 21 days. If 
you have fewer than 20 samples from the previous 21 days, continue 
keeping the most recent 20 samples collected up to a maximum of 90 days 
for any given sample.
    (5) The nominal volume of retained liquid samples must be at least 
330 ml. If you have only a single sample for testing, keep that sample 
after testing is complete. If you collect multiple samples from a single 
batch or you create a hand blend, select a representative sample as 
follows:
    (i) If you are required to test a hand blend under Sec.  1090.1340, 
keep a sample of the BOB and a sample representative of the oxygenate 
used to prepare the hand blend.
    (ii) For summer gasoline, keep an untested (or less tested) sample 
that is most like the tested sample, as applicable. In all other cases, 
keep the tested (or most tested) sample.
    (b) [Reserved]
    (c) Keep records of all calculations, test results, and test methods 
for the batch associated with each stored sample.
    (d) If EPA requests a test sample, you must follow EPA's 
instructions and send it to EPA by a courier service (or equivalent). 
The instructions will describe where and when to send the sample. For 
each test sample, you must identify the test results and test methods 
used.
    (e) You are responsible for meeting the requirements of this section 
even if a third party performs testing and stores the fuel samples for 
you.

                         Measurement Procedures



Sec.  1090.1350  Overview of test procedures.

    A fuel manufacturer, fuel additive manufacturer, regulated 
blendstock producer, or independent surveyor meets the requirements of 
this subpart based on laboratory measurements of the specified fuel 
parameters. Test procedures for these measurements apply as follows:
    (a) Except as specified in paragraph (b) of this section, the 
Performance-based Measurement System specified in Sec. Sec.  1090.1360 
through 1090.1375 applies

[[Page 598]]

for all testing specified in this subpart for the following fuels and 
fuel parameters:
    (1) Sulfur content of diesel fuel.
    (2) Sulfur content of ECA marine fuel.
    (3) RVP, sulfur content, benzene content, and oxygenate content of 
gasoline. The procedures for measuring sulfur in gasoline in this 
subpart also apply for testing sulfur in certified ethanol denaturant; 
however, demonstrating compliance for alternative procedures in Sec.  
1090.1365 and statistical quality control in Sec.  1090.1375 do not 
apply for sulfur concentration above 80 ppm.
    (4) Sulfur content of butane.
    (b) Specific test procedures apply for measuring other fuel 
parameters, as follows:
    (1) Determine the cetane index of diesel fuel as specified in ASTM 
D976 or ASTM D4737 (incorporated by reference in Sec.  1090.95). There 
is no cetane-related test requirement for biodiesel that meets ASTM 
D6751 (incorporated by reference in Sec.  1090.95).
    (2) Measure aromatic content of diesel fuel as specified in ASTM 
D1319 or ASTM D5186 (incorporated by reference in Sec.  1090.95). You 
may use an alternative procedure if you correlate your test results with 
ASTM D1319 or ASTM D5186. There is no aromatics-related test requirement 
for biodiesel that meets ASTM D6751.
    (3) Measure the purity of butane as specified in ASTM D2163 
(incorporated by reference in Sec.  1090.95). Measure the purity of 
pentane as specified in ASTM D2163 or ASTM D5134 (incorporated by 
reference in Sec.  1090.95).
    (4) Measure the benzene content of butane and pentane as specified 
in ASTM D2163, ASTM D5134, ASTM D6729, or ASTM D6730 (incorporated by 
reference in Sec.  1090.95).
    (5) Measure the sulfur content of pentane as specified in ASTM D5453 
(incorporated by reference in Sec.  1090.95).
    (6) Measure distillation parameters as specified in ASTM D86 
(incorporated by reference in Sec.  1090.95). You may use an alternative 
procedure if you correlate your test results with ASTM D86.
    (7) Measure the sulfur content of neat ethanol as specified in ASTM 
D5453. You may use an alternative procedure if you adequately correlate 
your test results with ASTM D5453.
    (8) Measure the phosphorus content of gasoline as specified in ASTM 
D3231 (incorporated by reference in Sec.  1090.95).
    (9) Measure the lead content of gasoline as specified in ASTM D3237 
(incorporated by reference in Sec.  1090.95).
    (10) Measure the sulfur content of gasoline additives and diesel 
fuel additives as specified in ASTM D2622 (incorporated by reference in 
Sec.  1090.95).
    (11) Use referee procedures specified in Sec.  1090.1360(d) and the 
following additional methods to measure gasoline fuel parameters to meet 
the survey requirements of subpart O of this part:

      Table 1 to Paragraph (b)(11)--Additional Survey Test Methods
------------------------------------------------------------------------
        Fuel parameter                Units           Test method \1\
------------------------------------------------------------------------
Distillation..................   [deg]C..........  ASTM D86.
Aromatic content..............  volume percent...  ASTM D5769.
Olefin content................  volume percent...  ASTM D6550.
------------------------------------------------------------------------
 \1\ ASTM specifications are incorporated by reference, see Sec.
  1090.95.

    (12) Updated versions of the test procedures specified in this 
section are acceptable as alternative procedures if both repeatability 
and reproducibility are the same or better than the values specified in 
the earlier version.
    (c) Record measured values with the following precision, with 
rounding in accordance with Sec.  1090.50:
    (1) Record sulfur content to the nearest whole ppm.
    (2) Record benzene to the nearest 0.01 volume percent.
    (3) Record RVP to the nearest 0.01 psi.
    (4) Record oxygenate content to the nearest 0.01 mass percent for 
each calibrated oxygenate.
    (5) Record diesel aromatic content to the nearest 0.1 volume 
percent, or record cetane index to the nearest whole number.

[[Page 599]]

    (6) Record gasoline aromatic and olefin content to the nearest 0.1 
volume percent.
    (7) Record distillation parameters to the nearest whole degree.
    (d) For any measurement or calculation that depends on the volume of 
the test sample, correct the volume of the sample to a reference 
temperature of 15.56 [deg]C. Use a correction equation that is 
appropriate for each tested compound. This applies for all fuels, 
blendstocks, and additives, except butane.



Sec.  1090.1355  Calculation adjustments and corrections.

    Adjust measured values as follows:
    (a) Adjust measured values for total vapor pressure as follows:

RVP (psi) = 0.956 [middot] Ptotal - 0.347

Where:

Ptotal = Measured total vapor pressure, in psi.

    (b) For measuring the sulfur content and benzene content of 
gasoline, adjust a given test result upward in certain circumstances, as 
follows:
    (1) If your measurement method involves a published procedure with a 
Pooled Limit of Quantitation (PLOQ), treat the PLOQ as your final result 
if your measured result is below the PLOQ.
    (2) If your measurement method involves a published procedure with a 
limited scope but no PLOQ, treat the lower bound of the scope as your 
final result if your measured result is less than that value.
    (3) If you establish a Laboratory Limit of Quantitation (LLOQ) below 
the lower bound of the scope of the procedure as specified in ASTM D6259 
(incorporated by reference in Sec.  1090.95), treat the LLOQ as your 
final result if your measured result is less than the LLOQ. Note that 
this option is meaningful only if the LLOQ is less than a published 
PLOQ, or if there is no published PLOQ.
    (c) For measuring the sulfur content of ULSD at a downstream 
location, subtract 2 ppm from the result.
    (d) For measuring the benzene content of butane and pentane, report 
a zero value if the test result is at or below the PLOQ or Limit of 
Detection (LOD) that applies for the test method.
    (e) If measured content of any oxygenate compound is less than 0.20 
percent by mass, record the result as ``None detected.''



Sec.  1090.1360  Performance-based Measurement System.

    (a) The Performance-based Measurement System (PBMS) is an approach 
that allows for laboratory testing with any procedure that meets 
specified performance criteria. This subpart specifies the performance 
criteria for measuring certain fuel parameters to demonstrate compliance 
with the standards and other specifications of this part. These 
provisions do not apply to process stream analyzers used with in-line 
blending.
    (b) Different requirements apply for absolute fuel parameters and 
method-defined fuel parameters.
    (1) Absolute fuel parameters are those for which it is possible to 
evaluate measurement accuracy by comparing measured values of a test 
sample to a reference sample with a known value for the measured 
parameter. The following are absolute fuel parameters:
    (i) Sulfur. This applies for measuring sulfur in any fuel, fuel 
additive, or regulated blendstock.
    (ii) [Reserved]
    (2) Method-defined fuel parameters are all those that are not 
absolute fuel parameters. Additional test provisions apply for method-
defined fuel parameters under this section because there is no reference 
sample for evaluating measurement accuracy.
    (c) The performance criteria of this section apply as follows:
    (1) Section 1090.1365 specifies the initial qualifying criteria for 
all measurement procedures. You may use an alternative procedure only if 
testing shows that you meet the initial qualifying criteria.
    (2) Section 1090.1375 specifies ongoing quality testing requirements 
that apply for a laboratory that uses either referee procedures or 
alternative procedures.
    (3) Streamlined requirements for alternative procedures apply for 
procedures adopted by a voluntary consensus standards body (VCSB). 
Certification testing with non-VCSB procedures requires advance approval 
by

[[Page 600]]

EPA. Procedures are considered non-VCSB testing as follows:
    (i) Procedures developed by individual companies or other parties 
are considered non-VCSB procedures.
    (ii) Draft procedures under development by a VCSB organization are 
considered non-VCSB procedures until they are approved for publication.
    (iii) A published procedure is considered non-VCSB for testing with 
fuel parameters that fall outside the range of values covered in the 
research report of the ASTM D6708 (incorporated by reference in Sec.  
1090.95) assessment comparing candidate alternative procedures to the 
referee procedure specified in paragraph (d) of this section.
    (4) You may use updated versions of the referee procedures as 
alternative procedures subject to the limitations of Sec.  
1090.1365(a)(2). You may ask EPA for approval to use an updated version 
of the referee procedure for qualifying other alternative procedures if 
the updated referee procedure has the same or better repeatability and 
reproducibility compared to the version specified in Sec.  1090.95. If 
the updated procedure has worse repeatability or reproducibility 
compared to the earlier version, you must complete the required testing 
specified in Sec.  1090.1365 using the older, referenced version of the 
referee procedure.
    (5) Any laboratory may use the specified referee procedure without 
qualification testing. To use alternative procedures at a given 
laboratory, you must perform the specified testing to demonstrate 
compliance with precision and accuracy requirements, with the following 
exceptions:
    (i) Testing you performed to qualify alternative procedures under 40 
CFR part 80 continues to be valid for making the demonstrations required 
in this part.
    (ii) Qualification testing is not required for a laboratory that 
measures the benzene content of gasoline using Procedure B of ASTM D3606 
(incorporated by reference in Sec.  1090.95). However, qualification 
testing may be necessary for updated versions of this procedure as 
specified in Sec.  1090.1365(a)(2).
    (d) Referee procedures are presumed to meet the initial qualifying 
criteria in this section. You may use alternative procedures if you 
qualify them using the referee procedures as a benchmark as specified in 
Sec.  1090.1365. The following are the referee procedures:

 Table 1 to Paragraph (d)--Referee Procedures for Qualifying Alternative
                               Procedures
------------------------------------------------------------------------
                                                       Referee procedure
         Tested product                Parameter              \1\
------------------------------------------------------------------------
ULSD, 500 ppm diesel fuel, ECA    Sulfur............  ASTM D2622.
 marine fuel, gasoline.
Butane..........................  Sulfur............  ASTM D6667.
Gasoline........................  oxygenate content.  ASTM D5599.
Gasoline........................  RVP...............  ASTM D5191, except
                                                       as specified in
                                                       Sec.
                                                       1090.1355(a).
Gasoline........................  benzene...........  ASTM D5769.
------------------------------------------------------------------------
\1\ ASTM specifications are incorporated by reference, see Sec.
  1090.95.



Sec.  1090.1365  Qualifying criteria for alternative measurement procedures.

    This section specifies how to qualify alternative procedures for 
measuring absolute and method-defined fuel parameters under the 
Performance-based Analytical Test Method specified in Sec.  1090.1360.
    (a) The following general provisions apply for qualifying 
alternative procedures:
    (1) Alternative procedures must have appropriate precision to allow 
for reporting to the number of decimal places specified in Sec.  
1090.1350(c).
    (2) Testing to qualify an alternative procedure applies for the 
specified version of the procedure you use for making the necessary 
measurements. For referee procedures and for alternative procedures for 
method-defined fuel parameters that you have qualified for your 
laboratory, updated versions of those same procedures are qualified 
without further testing, as long as the specified reproducibility is the 
same as or better than the values specified in the earlier version. For 
absolute fuel parameters, updated versions are qualified without testing 
if both repeatability and reproducibility are the same as or better than 
the values specified in the earlier version.
    (3) Except as specified in paragraph (d) of this section, testing to 
demonstrate compliance with the precision

[[Page 601]]

and accuracy specifications in this section apply only for the 
laboratory where the testing occurred.
    (4) If a procedure for measuring benzene or sulfur in gasoline has 
no specified PLOQ and no specified scope with a lower bound, you must 
establish a LLOQ for your laboratory.
    (5) Testing for method-defined fuel parameters must take place at a 
reference installation as specified in Sec.  1090.1370.
    (b) All alternative procedures must meet precision criteria based on 
a calculated maximum allowable standard deviation for a given fuel 
parameter as specified in this paragraph (b). The precision criteria 
apply for measuring the parameters and fuels specified in paragraph 
(b)(3) of this section. Take the following steps to qualify the 
measurement procedure for measuring a given fuel parameter:
    (1) The fuel must meet the parameter specifications in Table 1 to 
paragraph (b)(3) of this section. This may require that you modify the 
fuel you typically produce to be within the specified range. Absent a 
specification (maximum or minimum), select a fuel representing values 
that are typical for your testing. Store and mix the fuel to maintain a 
homogenous mixture throughout the measurement period to ensure that each 
fuel sample drawn from the batch has the same properties.
    (2) Measure the fuel parameter from a homogeneous fuel batch at 
least 20 times. Record each result in sequence. Do not omit any valid 
results unless you use good engineering judgment to determine that the 
omission is necessary and you document those results and the reason for 
excluding them. Perform this analysis over a 20-day period. You may make 
up to 4 separate measurements in a 24-hour period, as long as the 
interval between measurements is at least 4 hours. Do not measure RVP 
more than once from a single sample.
    (3) Calculate the maximum allowable standard deviation as follows:
    [GRAPHIC] [TIFF OMITTED] TR04DE20.018
    
Where:
[sigma]max = Maximum allowable standard deviation.
x1, x2, and x3 have the values from the 
          following table:

[[Page 602]]



                                                      Table 1 to Paragraph (b)(3)--Precision Criteria for Qualifying Alternative Procedures
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                                                                                            Fixed
 Fuel, fuel additive, or regulated      Fuel parameter             Range             x1         x2 = Repeatability (r) or          x3     values of                   Source \2\
            blendstock                                                                           reproducibility (R) \1\                 [sigma]max
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
ULSD..............................  Sulfur...............  5 ppm minimum........      1.5  r = 1.33...........................     2.77       0.72   ASTM D3120-08 (R2019).
500 ppm LM diesel fuel............  Sulfur...............  350 ppm minimum......      1.5  r = 21.3...........................     2.77       11.5   ASTM D2622-16.
ECA marine fuel...................  Sulfur...............  700 ppm minimum......      1.5  37.1...............................     2.77       20.1   ASTM D2622-16.
Butane............................  Sulfur...............  .....................      1.5  r = 0.1152.x.......................     2.77  ..........  ASTM D6667-14 (R2019).
Gasoline..........................  Sulfur...............  .....................      1.5  r = 0.4998.x \0.54\................     2.77  ..........  ASTM D7039-15a (R2020).
Gasoline..........................  oxygenate............  .....................      0.3  R = 0.13.x \0.83\..................        1  ..........  ASTM D5599-18.
Gasoline..........................  RVP \3\..............  .....................      0.3  R = 0.40...........................        1       0.12   ASTM D5191-20.
Gasoline..........................  Benzene..............  .....................     0.15  R = 0.221.x \0.67\.................        1  ..........  ASTM D5769-20.
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
\1\ Calculate repeatability and reproducibility using the average value determined from testing. Use units as specified in Sec.   1090.1350(c).
\2\ ASTM publications are incorporated by reference, see Sec.   1090.95. Note that the listed procedure may be different than the referee procedure identified in Sec.   1090.1360(d), or it may
  be an older version of the referee procedure.
\3\ Use only 1-liter containers for testing to qualify alternative methods.


[[Page 603]]

    (c) Alternative VCSB procedures for measuring absolute fuel 
parameters (sulfur) must meet accuracy criteria based on the following 
measurement procedure:
    (1) Obtain gravimetric sulfur standards to serve as representative 
reference samples. The samples must have known sulfur content within the 
ranges specified in paragraph (c)(3) of this section. The known sulfur 
content is the accepted reference value (ARV) for the fuel sample.
    (2) Measure the sulfur content of the fuel sample at your laboratory 
at least 10 times, without interruption. Use good laboratory practice to 
compensate for any known chemical interferences; however, you must apply 
that same compensation for all tests to measure the sulfur content of a 
test fuel. Calculate the arithmetic average of all the measured values, 
including any compensation.
    (3) The measurement procedure meets the accuracy requirement as 
follows:
    (i) Demonstrate accuracy for measuring sulfur in gasoline, gasoline 
regulated blendstock, and gasoline additive using test fuels to 
represent sulfur values from 1 to 10 ppm, 11 to 20 ppm, and 21 to 95 
ppm. You may omit any of these ranges if you do not perform testing with 
fuel in that range. Calculate the maximum allowable difference between 
the average measured value and ARV for each applicable range as follows:

    [Delta]max = 0.75 [middot] [sigma]max

Where:
[Delta]max = Maximum allowable difference.
[sigma]max = the maximum allowable standard deviation from 
          paragraph (b)(3) of this section using the sulfur content 
          represented by ARV.

    (ii) Demonstrate accuracy for measuring sulfur in diesel fuel using 
test fuels meeting the specifications in Table 2 to this section. For 
testing diesel-related blendstocks and additives, use representative 
test samples meeting the appropriate sulfur specification. Table 2 to 
this paragraph also identifies the maximum allowable difference between 
average measured values and ARV corresponding to ARV at the upper end of 
the specified ranges. These values are based on calculations with the 
equation in paragraph (c)(3)(i) of this section, with parameter values 
set to be equal to the standard.

    Table 2 to Paragraph (c)(3)(ii)--Accuracy Criteria for Qualifying
 Alternative Procedures With Diesel Fuel and Diesel-Related Blendstocks
                              and Additives
------------------------------------------------------------------------
                                                            Illustrated
                                          Sulfur content      maximum
                  Fuel                         (ppm)         allowable
                                                            differences
------------------------------------------------------------------------
ULSD....................................           10-20            0.54
500 ppm LM diesel fuel..................         450-500            8.65
ECA marine fuel.........................       900-1,000            15.1
------------------------------------------------------------------------

    (d) Alternative VCSB procedures for measuring method-defined fuel 
parameters must meet accuracy criteria as follows:
    (1) You may use the alternative procedure only if you follow all the 
statistical protocols and meet all the criteria specified in Section 6 
of ASTM D6708 (incorporated by reference in Sec.  1090.95) when 
comparing your measurements using the alternative procedure to 
measurements at a reference installation using the appropriate referee 
procedure identified in Sec.  1090.1360(d).
    (2) For qualifying alternative procedures, determine whether the 
alternative procedure needs a correlation equation to correct bias 
relative to the reference test method. Create such a correlation 
equation as specified in Section 7 of ASTM D6708. For all testing, apply 
the correlation equation to adjust measured values to be statistically 
consistent to measuring with the reference test method.
    (3) If an alternative VCSB procedure states that the procedure has a 
successful assessment relative to the referee procedures in this section 
under ASTM D6708, that finding applies for all laboratories using that 
procedure.
    (e) Alternative non-VCSB procedures for measuring absolute fuel 
parameters (sulfur) must meet accuracy criteria as follows:
    (1) Demonstrate whether the procedure meets statistical criteria and 
whether it needs a correlation equation as specified in paragraphs 
(d)(1) and (2) of this section. Apply the correlation equation for all 
testing with the alternative procedure.

[[Page 604]]

    (2) Demonstrate at your laboratory that the alternative procedure 
meets the accuracy criteria specified in paragraph (c) of this section.
    (3) Send EPA a written request to use the alternative procedure. In 
your request, fully describe the procedure to show how it functions for 
achieving accurate measurements and include detailed information related 
to your assessment under paragraph (e)(1) and (2) of this section.
    (f) Alternative non-VCSB procedures for measuring method-defined 
fuel parameters must meet accuracy and precision criteria as follows:
    (1) Demonstrate whether the procedure meets statistical criteria and 
whether it needs a correlation equation as specified in paragraphs 
(e)(1) and (2) of this section. Apply the correlation equation for all 
testing with the alternative procedure.
    (2) Test with a range of fuels that are typical of those you will 
analyze at your laboratory. Use either consensus-named fuels or locally-
named reference materials. Consensus-named fuels are homogeneous fuel 
quantities sent around to different laboratories for analysis, which 
results in a ``consensus name'' representing the average value of the 
parameter for all participating laboratories. Locally named reference 
materials are fuel samples analyzed using the reference test method, 
either at your laboratory or at a reference installation, to establish 
an estimated value for the fuel parameter; locally named reference 
materials usually come from the fuel you produce.
    (3) You may qualify your procedure as meeting the requirements of 
paragraph (f)(1) of this section only for a narrower, defined range of 
fuels. If this is the case, identify the appropriate range of fuels in 
your request for approval and describe how you will screen fuel samples 
accordingly.
    (4) Qualify the precision of the alternative procedure by comparing 
results to testing with the referee procedure based on ``between methods 
reproducibility,'' Rxy, as specified in ASTM D6708. The Rxy must be at 
or below 75 percent of the reproducibility of the referee procedure in 
Sec.  1090.1360(d).
    (5) Perform testing at your laboratory as specified in paragraph (b) 
of this section to establish the repeatability of the alternative 
procedure. The repeatability must be as good as or better than that 
specified in paragraph (b)(3) of this section.
    (6) Fully describe the procedure to show how it functions for 
achieving accurate measurements. Describe the technology, test 
instruments, and testing method so a competent person lacking experience 
with the procedure and test instruments would be able to replicate the 
results.
    (7) Engage a third-party auditor to review and verify your 
information as follows:
    (i) The auditor must qualify as an independent third party and meet 
the specifications for technical ability as specified in Sec.  1090.55.
    (ii) The auditor must send you a report describing their inspection 
of your laboratories and their review of the information supporting your 
request to use the alternative procedure. The report must describe how 
the auditor performed the review, identify any errors or discrepancies, 
and state whether the information supports a conclusion that the 
alternative procedure should be approved.
    (iii) The auditor must keep records related to the review for at 
least 5 years after sending you the report and provide those records to 
EPA upon request.
    (8) Send EPA a written request to use the alternative procedure. 
Include the specified information and any additional information EPA 
needs to evaluate your request.
    (g) Keep fuel samples from any qualification testing under this 
section for at least 180 days after you have taken all steps to qualify 
an alternative procedure under this section. This applies for testing at 
your laboratory and at any reference installation you use for 
demonstrating the accuracy of an alternative procedure.



Sec.  1090.1370  Qualifying criteria for reference installations.

    (a) A reference installation refers to a laboratory that uses the 
referee procedure specified in Sec.  1090.1360(d) to evaluate the 
accuracy of alternative procedures for method-defined parameters, by 
comparing measured values to

[[Page 605]]

companion tests using one of the referee procedures in Sec.  
1090.1360(d). This evaluation may result in an equation to correlate 
results between the two procedures. Once a laboratory qualifies as a 
reference installation, that qualification is valid for five years from 
the qualifying date, consistent with good laboratory practices.
    (b) You may qualify a reference installation for VCSB procedures by 
participating in an interlaboratory crosscheck program with at least 16 
separate measurements that are not identified as outliers. This presumes 
that the results for the candidate reference installation are not 
outliers.
    (c) You may qualify a reference installation for VCSB or non-VCSB 
procedures based on the following measurement protocol:
    (1) Use the precision testing procedure specified in Sec.  
1090.1365(b) to show that your standard deviation for tests using the 
reference test method is at or below 0.3 times the reproducibility for a 
given fuel parameter.
    (2) You must correlate your test results for a given fuel parameter 
against the accepted reference values from a monthly crosscheck program 
based on Section 6.2.2.1 and Note 7 of ASTM D6299 (incorporated by 
reference in Sec.  1090.95) as follows:
    (i) If there are multiple fuels available from the crosscheck 
program, select the fuel that has the closest value to the standard. If 
there is no standard for a given fuel parameter, select the fuel with 
values for the fuel parameter that best represent typical values for 
fuels you test.
    (ii) Measure the fuel parameter for the crosscheck fuel at your 
laboratory using the appropriate referee procedure. Calculate a mean 
value that includes all your repeat measurements.
    (iii) Determine the mean value from the crosscheck program and 
calculate the difference between this value and the mean value from your 
testing. Express this difference as a certain number of standard 
deviations relative to the data set from the crosscheck program.
    (iv) The calculated monthly difference between the mean values from 
Sec.  1090.1365(c)(3)(ii) for 5 consecutive months must fall within the 
central 50 percent of the distribution of data at least 3 times. The 
central 50 percent of the distribution corresponds to 0.68 standard 
deviations.
    (v) Calculate the mean value of the differences from Sec.  
1090.1365(c)(3)(ii) for all 5 months. This mean value must fall within 
the central 50 percent of the distribution of data from the crosscheck 
program. For example, if the difference was 0.5 standard deviations for 
two months, 0.6 for one month, and 0.7 for two months, the mean value of 
the difference is 0.6 standards deviations, and the reference 
installation meets the requirements of this paragraph.
    (3) You must demonstrate that the reference installation is in 
statistical quality control for at least 5 months with the designated 
procedure as specified in ASTM D6299. If at any point the reference 
installation is not in statistical quality control, you must make any 
necessary changes and restart testing toward meeting the requirement to 
achieve statistical quality control for at least 5 months, except as 
follows:
    (i) Do not consider measurements you perform as part of regular 
maintenance or recalibration for evaluating statistical quality control.
    (ii) If you find that the reference installation is not in 
statistical quality control during an initial 5-month period and you are 
able to identify the problem and make the necessary changes to again 
achieve statistical quality control before the end of the 5-month 
demonstration period, you may consider the reference installation as 
meeting the requirement to be in statistical quality control for at 
least 5 months.



Sec.  1090.1375  Quality control procedures.

    This section specifies ongoing quality testing requirements as part 
of the Performance-based Measurement System specified in Sec.  
1090.1360.
    (a) General provisions. You must perform testing to show that your 
laboratory meets specified precision and accuracy criteria as follows:
    (1) The testing requirement applies for the referee procedures in 
Sec.  1090.1360(d) and for alternate procedures that are qualified or 
approved

[[Page 606]]

under Sec.  1090.1365. The testing requirements apply separately for 
each test instrument at each laboratory.
    (2) If you fail to conduct specified testing, your test instrument 
is not qualified for measuring fuel parameters to demonstrate compliance 
with the standards and other specifications of this part until you 
perform this testing. Similarly, if your test instrument fails to meet 
the specified criteria, it is not qualified for measuring fuel 
parameters to demonstrate compliance with the standards and other 
specifications of this part until you make the necessary changes to your 
test instrument and perform testing to show that the test instrument 
again meets the specified criteria.
    (3) If you perform major maintenance such as overhauling an 
instrument, confirm that the instrument still meets precision and 
accuracy criteria before you start testing again based on the procedures 
specified in ASTM D6299 (incorporated by reference in Sec.  1090.95).
    (4) Keep records to document your testing under this section for 5 
years.
    (b) Precision demonstration. Show that you meet precision criteria 
as follows:
    (1) Meeting the precision criteria of this paragraph (b) qualifies 
your test instrument for performing up to 20 tests or 7 days, whichever 
is less. Include all tests except for testing to meet precision or 
accuracy requirements.
    (2) Perform precision testing using the control-chart procedures in 
ASTM D6299. If you opt to use procedure 2A (Q-Procedure) or 2B 
(dynamically updated exponentially weighted moving average), validate 
the first run on the new QC batch by either an overlap in-control result 
of the old batch, or by a single execution of an accompanying standard 
reference material. The new QC material result would be considered 
validated if the single result of the standard reference material is 
within the established site precision (R') of the ARV of the standard 
reference material.
    (3) Use I charts and MR charts as specified in ASTM D6299 to show 
that the standard deviation for the test instrument meets the precision 
criteria specified in Sec.  1090.1365(b).
    (c) Accuracy demonstration. For absolute fuel parameters (VCSB and 
non-VCSB) and for method-defined fuel parameters using non-VCSB methods, 
you must show that you meet accuracy criteria as specified in this 
paragraph (c). For method-defined VCSB procedures, you may meet accuracy 
requirements as specified in this paragraph (c) or by comparing your 
results to the accepted reference value in an inter-laboratory 
crosscheck program sponsored by ASTM International or another VCSB at 
least 3 times per year.
    (1) Meeting the accuracy criteria of this paragraph (c) qualifies 
your test instrument for 130 days.
    (2) Except as specified in paragraph (c)(3) of this section, test 
every instrument using a check standard meeting the specifications of 
ASTM D6299. Select a fuel sample with an ARV that is at or slightly 
below the standard that applies. If there are both average and batch 
standards, use the average standard. If there is no standard, select a 
fuel sample representing fuel that is typical for your testing.
    (3) The following provisions apply for method-defined non-VCSB 
alternative procedures with high sensitivity to sample-specific bias:
    (i) Procedures have high sensitivity if the closeness sum of squares 
(CSS) statistic exceeds the 95th percentile value, as specified in ASTM 
D6708 (incorporated by reference in Sec.  1090.95).
    (ii) Create a check standard from production fuel representing the 
fuel you will routinely analyze. Determine the ARV of your check 
standard using the protocol in ASTM D6299 at a reference installation as 
specified in Sec.  1090.1370.
    (iii) You must send EPA a fuel sample from every twentieth batch of 
gasoline or diesel fuel and identify the procedures and corresponding 
test results from your testing. EPA may return one of your samples to 
you for further testing; if this occurs, you must repeat your 
measurement and report your results within 180 days of receiving the 
fuel sample.
    (4) You meet accuracy requirements under this section if the 
difference between your measured value for the check standard and the 
ARV is less

[[Page 607]]

than the value from the following equation:
[GRAPHIC] [TIFF OMITTED] TR04DE20.019

Where:
[Delta]max = Maximum allowable difference.
R = Reproducibility of the referee procedure identified in Sec.  
          1090.1360(d), as noted in Table 1 to paragraph (b)(3) of Sec.  
          1090.1365 or in the following table:


                   Table 1 to Paragraph (c)(4)--Criteria for Qualifying Alternative Procedures
----------------------------------------------------------------------------------------------------------------
            Tested product                Referee procedure \1\               Reproducibility (R) \2\
----------------------------------------------------------------------------------------------------------------
ULSD, 500 ppm diesel fuel, ECA marine   ASTM D2622..............  R = 0.4273 [middot] x \0.8015\
 fuel, diesel fuel additive, gasoline,
 gasoline regulated blendstock, and
 gasoline additive.
Butane................................  ASTM D6667..............  R = 0.3130 [middot] x
----------------------------------------------------------------------------------------------------------------
\1\ ASTM specifications are incorporated by reference, see Sec.   1090.95.
\2\ Calculate reproducibility using the average value determined from testing. Use units as specified in Sec.
  1090.1350(c).


L = the total number of test results used to determine the ARV of a 
          consensus-named fuel. For testing locally named fuels for 
          which no consensus-based ARV applies, use L = [infin].

               Testing Related to Gasoline Deposit Control



Sec.  1090.1390  Requirement for Automated Detergent 
Blending Equipment Calibration.

    (a) An automated detergent blending facility must calibrate their 
automated detergent blending equipment once in each calendar half-year, 
with the acceptable calibrations being no less than 120 days apart.
    (b) Equipment recalibration is also required each time the detergent 
package is changed, unless written documentation indicates that the new 
detergent package has the same viscosity as the previous detergent 
package. Calibrating after changing the detergent package may be used to 
satisfy the semiannual recalibration requirement in paragraph (a) of 
this section, provided that the calibrations occur in the appropriate 
calendar half-year and are no less than 120 days apart.



Sec.  1090.1395  Gasoline deposit control test procedures.

    A gasoline detergent manufacturer must perform testing using one of 
the methods specified in this section to establish the lowest additive 
concentration (LAC) for the detergent.
    (a) Top Tier-Based Test Method. Use the procedures specified in ASTM 
D6201 (incorporated by reference in Sec.  1090.95), as follows:
    (1) Use a base fuel that conforms to the specifications for 
gasoline-alcohol blends in ASTM D4814 (incorporated by reference in 
Sec.  1090.95). Blendstocks used to formulate the test fuel must be 
derived from conversion units downstream of distillation, with all 
processes representing normal fuel manufacturing facility operations. 
Blendstocks must not come from chemical grade streams. Butane and 
pentane may be added to adjust vapor pressure. The base fuel should 
include any nondetergent additives typical of commercially available 
fuel if they may positively or negatively affect deposit formation. In 
addition, the base fuel must have the following properties:
    (i) 8.0-10.0 volume percent DFE that meets the requirements in Sec.  
1090.270 and conforms to the specifications of ASTM D4806 (incorporated 
by reference in Sec.  1090.95).
    (ii) At least 8.0 volume percent olefins.
    (iii) At least 15 volume percent aromatics.
    (iv) No more than 80 ppm sulfur.
    (v) T90 distillation temperature at or above 143 [deg]C.
    (vi) No detergent-active substance. A base fuel with typical 
nondetergent additives, such as antioxidants, corrosion inhibitors, and 
metal deactivators, may be used.
    (2) Perform the 100-hour test for intake valve deposits with the 
base fuel to demonstrate that the intake valves

[[Page 608]]

accumulate at least 500 mg on average. If the test engine fails to 
accumulate enough deposits, make any necessary adjustments and repeat 
the test. This demonstration is valid for any further detergent testing 
with the same base fuel.
    (3) Repeat the test on the same engine with a specific concentration 
of detergent added to the base fuel. If the test results in less than 50 
mg average per intake valve, the tested detergent concentration is the 
LAC for the detergent.
    (b) CARB Test Method. Use the procedures specified by CARB in Title 
13, California Code of Regulations, section 2257 (incorporated by 
reference in Sec.  1090.95).
    (1) A detergent tested under this option or certified under 40 CFR 
80.163(d) prior to January 21, 2021, may be used at the LAC specified 
for use in the state of California in any gasoline in the United States.
    (2) The gasoline detergent manufacturer must cease selling a 
detergent immediately upon being notified by CARB that the CARB 
certification for this detergent has been invalidated and must notify 
EPA under 40 CFR 79.21.
    (c) EPA BMW method. Use the procedures specified in ASTM D5500 
(incorporated by reference in Sec.  1090.95), as follows:
    (1) Prepare the test fuel with the following specification:
    (i) Sulfur--minimum 340 ppm.
    (ii) T90--minimum 171 [deg]C.
    (iii) Olefins--minimum 11.4 volume percent.
    (iv) Aromatics--minimum 31.1 volume percent.
    (v) Ethanol--minimum 10 volume percent.
    (vi) Sulfur, T90, olefins, and aromatics specifications must be met 
before adding ethanol.
    (vii) Di-tert-butyl disulfide may be added to the test fuel.
    (2) The duration of testing may be less than 10,000 miles. Measured 
deposits must meet the following specified values to qualify the test 
fuel and establish a detergent's LAC:
    (i) Measured deposits for the fuel without detergent must be at 
least 290 mg per valve on average.
    (ii) Measured deposits for the fuel with detergent must be less than 
100 mg per valve on average.
    (d) Alternative test methods. (1) An EPA-approved alternative test 
method may be used if the alternative test method can be correlated to 
any of the methods specified in paragraphs (a) through (c) of this 
section.
    (2) Information describing the alternative test method and analysis 
demonstrating correlation must be submitted for EPA approval as 
specified in Sec.  1090.10.



                       Subpart O_Survey Provisions



Sec.  1090.1400  General provisions.

    (a) Program plan approval process. (1) A program plan that complies 
with the requirements in Sec.  1090.1415 or Sec.  1090.1450 must be 
submitted to EPA no later than October 15 of the year preceding the 
calendar year in which the program will be conducted.
    (2) The program plan must be signed by an RCO of the independent 
surveyor conducting the program.
    (3) The program plan must be submitted as specified in Sec.  
1090.10.
    (4) EPA will send a letter to the party submitting the program plan 
that indicates whether EPA approves or disapproves the plan.
    (b) Independent surveyor contract. (1) No later than December 15 of 
the year preceding the year in which the survey will be conducted, the 
contract with the independent surveyor must be in effect, and the amount 
of compensation necessary to carry out the entire survey plan must 
either be paid to the independent surveyor or placed into an escrow 
account with instructions to the escrow agent to remit the compensation 
to the independent surveyor during the course of the survey plan.
    (2) No later than December 31 of the year preceding the year in 
which the survey will be conducted, EPA must receive a copy of the 
contract with the independent surveyor and proof that the compensation 
necessary to carry out the survey plan has either been paid to the 
independent surveyor or placed into an escrow account. If placed into an 
escrow account, a copy of the escrow agreement must be sent to EPA.

[[Page 609]]



Sec.  1090.1405  National fuels survey program.

    (a) Program participation. (1) A gasoline manufacturer that elects 
to account for oxygenate added downstream under Sec.  1090.710 must 
participate in the national fuels survey program (NFSP) specified in 
this paragraph (b) of this section.
    (2) A party required to participate in an E15 survey under Sec.  
1090.1420(a) must participate in the NFSP specified in paragraph (b) of 
this section or a survey program approved by EPA under Sec.  
1090.1420(b) or (c).
    (3) Other parties may elect to participate in the NFSP for purposes 
of establishing an affirmative defense against violations of 
requirements and provisions under this part as specified in Sec.  
1090.1720.
    (b) Program requirements. The NFSP must meet all the following 
requirements:
    (1) The survey program must be planned and conducted by an 
independent surveyor that meets the independence requirements in Sec.  
1090.55 and the requirements specified in Sec.  1090.1410.
    (2) The survey program must be conducted by collecting samples 
representative of gasoline and diesel retail outlets in the United 
States as specified in Sec.  1090.1415.



Sec.  1090.1410  Independent surveyor requirements.

    The independent surveyor conducting the NFSP must meet all the 
following requirements:
    (a) Submit a proposed survey program plan under Sec.  1090.1415 to 
EPA for approval for each calendar year.
    (b)(1) Obtain samples representative of the gasoline and diesel fuel 
(including diesel fuel made available at retail to nonroad vehicles, 
engines, and equipment) offered for sale separately from all gasoline 
and diesel retail outlets in accordance with the survey program plan 
approved by EPA, or immediately notify EPA of any refusal of a retailer 
to allow samples to be taken.
    (2) Obtain the number of samples representative of the number of 
gasoline retail outlets offering E15.
    (3) Collect samples of gasoline produced at blender pump using 
``method 1'' specified in NIST Handbook 158 (incorporated by reference, 
see Sec.  1090.95). All other samples of gasoline and diesel fuel must 
be collected using the methods specified in subpart N of this part.
    (4) Samples must be shipped via ground service to an EPA-approved 
laboratory within 2 business days of being collected.
    (c) Test, or arrange to be tested, the collected samples, as 
follows:
    (1) Gasoline samples must be analyzed for oxygenate content, sulfur 
content, and benzene content. Gasoline samples collected from June 1 
through September 15 must also be analyzed for RVP.
    (2) A subset of gasoline samples, as determined under Sec.  
1090.1415(e)(3), must also be analyzed for aromatics content, olefins 
content, and distillation parameters.
    (3) Diesel samples must be analyzed for sulfur content.
    (4) All samples must be tested by an EPA-approved laboratory using 
the test methods specified in subpart N of this part.
    (5) All testing must be completed by the EPA-approved laboratory 
within 10 business days after receipt of the sample.
    (d) Verify E15 labeling requirements at gasoline retail outlets that 
offer E15 for sale.
    (e) Using procedures specified in an EPA-approved plan under Sec.  
1090.1415, notify EPA, the retailer, and the branded fuel manufacturer 
(if applicable) within 24 hours after the EPA-approved laboratory has 
completed analysis when any of the following occur:
    (1) A test result for a gasoline sample yields a sulfur content 
result that exceeds the downstream sulfur per-gallon standard in Sec.  
1090.205(c).
    (2) A test result for a gasoline sample yields an RVP result that 
exceeds the applicable RVP standard in Sec.  1090.215.
    (3) A test result for a diesel sample yields a sulfur content result 
that exceeds the sulfur standard in Sec.  1090.305(b).
    (4) A test result for a gasoline sample identified as ``E15'' yields 
an ethanol content result that exceeds 15 volume percent.

[[Page 610]]

    (5) A test result for a gasoline sample not identified as ``E15'' 
yields an ethanol content of more than 10 volume percent ethanol.
    (f) Provide quarterly and annual summary reports that include the 
information specified in Sec.  1090.925(b) and (c), respectively.
    (g) Keep records related to the NFSP as specified in Sec.  
1090.1245(b)(1).
    (h) Submit contracts to EPA as specified in Sec.  1090.1400(b).
    (i) Permit any representative of EPA to monitor at any time the 
conducting of the survey, including sample collection, transportation, 
storage, and analysis.



Sec.  1090.1415  Survey program plan design requirements.

    The survey program plan must include all the following:
    (a) Number of surveys. The survey program plan must include 4 
surveys each calendar year that occur during the following time periods:
    (1) One survey during the period of January 1 through March 31.
    (2) One survey during the period of April 1 through June 30.
    (3) One survey during the period of July 1 through September 30.
    (4) One survey during the period of October 1 through December 31.
    (b) Sampling areas. The survey program plan must include sampling in 
all sampling strata during each survey. These sampling strata must be 
further divided into discrete sampling areas or clusters. Each survey 
must include sampling in at least 40 sampling areas in each stratum that 
are randomly selected.
    (c) No advance notice of surveys. The survey program plan must 
include procedures to keep the identification of the sampling areas that 
are included in the plan confidential from any participating party prior 
to the beginning of a survey in an area. However, this information must 
not be kept confidential from EPA.
    (d) Gasoline and diesel retail outlet selection. (1) Gasoline and 
diesel retail outlets to be sampled in a sampling area must be selected 
from among all gasoline retail outlets in the United States that sell 
gasoline with the probability of selection proportionate to the volume 
of gasoline sold at the retail outlet. The sample of retail outlets must 
also include gasoline retail outlets with different brand names as well 
as those gasoline retail outlets that are unbranded.
    (2) For any gasoline or diesel retail outlet from which a sample of 
gasoline or diesel was collected during a survey and was reported to EPA 
under Sec.  1090.1410(e), that gasoline or diesel retail outlet must be 
included in the subsequent survey.
    (3) At least one sample of a product dispensed as E15 must be 
collected at each gasoline retail outlet when E15 is present, and 
separate samples must be taken that represent the gasoline contained in 
each storage tank at the gasoline retail outlet unless collection of 
separate samples is not practicable.
    (4) At least one sample of a product dispensed as diesel fuel must 
be collected at each diesel fuel retail outlet when diesel fuel is 
present. Samples of diesel fuel may be collected at retail outlets that 
sell gasoline.
    (e) Number of samples. (1) The number of retail outlets to be 
sampled must be independently calculated for the total number of 
gasoline retail outlets and the total number of diesel fuel retail 
outlets. The same retail outlet may represent both a gasoline retail 
outlet and a diesel fuel retail outlet for purposes of determining the 
number of samples.
    (2) The minimum number of samples to be included in the survey 
program plan for each calendar year is calculated as follows:
[GRAPHIC] [TIFF OMITTED] TR04DE20.020


[[Page 611]]


Where:

n = Minimum number of samples in a year-long survey series. However, n 
          must be greater than or equal to 2,000 for the number of 
          diesel samples or 5,000 for the number of gasoline samples.
Z[alpha] = Upper percentile point from the normal 
          distribution to achieve a one-tailed 95% confidence level (5% 
          [alpha]-level). For purposes of this survey program, 
          Z[alpha] equals 1.645.
Z[beta] = Upper percentile point to achieve 95% power. For 
          purposes of this survey program, Z[beta] equals 
          1.645.
[phiv]1 = The maximum proportion of non-compliant outlets for 
          a region to be deemed compliant. This parameter needs to be 5% 
          or greater (i.e., 5% or more of the outlets, within a stratum 
          such that the region is considered non-compliant).
[phiv]0 = The underlying proportion of non-compliant outlets 
          in a sample. For the first survey program plan, 
          [phiv]0 will be 2.3%. For subsequent survey program 
          plans, [phiv]0 will be the average of the 
          proportion of outlets found to be non-compliant over the 
          previous 4 surveys.
Fa = Adjustment factor for the number of extra samples 
          required to compensate for samples that could not be included 
          in the survey (e.g., due to technical or logistical 
          considerations), based on the number of additional samples 
          required during the previous 4 surveys. Fa must be 
          greater than or equal to 1.1.
Fb = Adjustment factor for the number of samples required to 
          resample each retail outlet with test results reported to EPA 
          under Sec.  1090.1410(e), based on the rate of resampling 
          required during the previous 4 surveys. Fb must be 
          greater than or equal to 1.1.
Sun = Number of surveys per year. For purposes of this survey 
          program, Sun equals 4.
Stn = Number of sampling strata. For purposes of this survey 
          program, Stn equals 3.

    (3) The number of gasoline samples that also need to be tested for 
aromatics, olefins, and distillation parameters under Sec.  
1090.1410(c)(2) must be calculated using the methodology specified in 
paragraph (e)(2) of this section without the Fa, 
Fb, and Sun parameters.
    (4) The number of samples determined under paragraphs (e)(2) and (3) 
of this section must be distributed approximately equally among the 4 
surveys conducted during the calendar year.
    (f) Laboratory designation. Any laboratory that the independent 
surveyor intends to use to test samples collected as part of the NFSP 
must be approved annually as part of the survey program plan approval 
process in Sec.  1090.1400(a). In the survey program plan submitted to 
EPA, the independent surveyor must include the following information 
regarding any laboratory they intend to use to test samples:
    (1) The name of the laboratory.
    (2) The address of the laboratory.
    (3) The test methods for each fuel parameter measured at the 
laboratory.
    (4) Reports demonstrating the laboratory's performance in a 
laboratory crosscheck program for the most recent 12 months prior to 
submission of the survey program plan.
    (g) Submission. Survey program plans submitted under this section 
must be approved annually under Sec.  1090.1400(a).



Sec.  1090.1420  Additional requirements for E15 misfueling mitigation surveying.

    (a) E15 misfueling mitigation survey requirement. (1) Any gasoline 
manufacturer, oxygenate blender, or oxygenate producer that produces, 
introduces into commerce, sells, or offers for sale E15, gasoline, BOB, 
DFE, or gasoline-ethanol blended fuel that is intended for use in or as 
E15 must comply with either survey program Option 1 (as specified in 
paragraph (b) of this section) or Option 2 (as specified in paragraph 
(c) of this section).
    (2) For an oxygenate producer that produces or imports DFE, the DFE 
is deemed as intended for use in E15 unless the oxygenate producer 
demonstrates that it was not intended for such use. The oxygenate 
producer may demonstrate, at a minimum, that DFE is not intended for use 
in E15 by including language on PTDs stating that the DFE is not 
intended for use in E15, entering into contracts with oxygenate blenders 
to limit the use of their DFE to gasoline-ethanol blended fuels of no 
more than 10 volume percent, and limiting the concentration of their DFE 
to no more than 10 volume percent in their fuel additive registration 
under 40 CFR part 79.
    (b) Survey Option 1. The gasoline manufacturer, oxygenate blender, 
or oxygenate producer must properly conduct a survey program in 
accordance with a survey program plan that has

[[Page 612]]

been approved by EPA in all areas that may be reasonably expected to be 
supplied with their gasoline, BOB, DFE, or gasoline-ethanol blended 
fuel. Such approval must be based on a survey program plan that meets 
all the following requirements:
    (1) The survey program must consist of at least quarterly surveys 
that occur during the following time periods in every year during which 
the gasoline manufacturer, oxygenate blender, or oxygenate producer 
introduces E15 into commerce:
    (i) One survey during the period of January 1 through March 31.
    (ii) One survey during the period of April 1 through June 30.
    (iii) One survey during the period of July 1 through September 30.
    (iv) One survey during the period of October 1 through December 31.
    (2) The survey program plan must meet all the requirements of this 
subpart, except for Sec. Sec.  1090.1405(a) and (b)(2), 1090.1410(c)(2) 
and (3), and 1090.1415(b), (d)(1), (2), and (4), and (e). In lieu of 
meeting these sections, the survey program plan must specify the 
sampling strata, clusters, and area(s) to be surveyed, and the number of 
samples to be included in the survey.
    (c) Survey Option 2. The gasoline manufacturer, oxygenate blender, 
or oxygenate producer must participate in the NFSP under Sec.  
1090.1405.



Sec.  1090.1450  National sampling and testing oversight program.

    (a) Program participation. (1) Except for a gasoline manufacturer 
that has an approved in-line blending waiver under Sec.  1090.1315 that 
covers all gasoline produced at their facility, a gasoline manufacturer 
that elects to account for oxygenate added downstream under Sec.  
1090.710 must participate in the national sampling and testing oversight 
program (NSTOP) in this section.
    (2) Other gasoline manufacturers may elect to participate in the 
NSTOP for purposes of establishing an affirmative defense to a violation 
under Sec.  1090.1720. A gasoline manufacturer that has an approved in-
line blending waiver under Sec.  1090.1315 does not need to participate 
in the NSTOP in order to establish an affirmative defense to a violation 
under Sec.  1090.1720.
    (3) A gasoline manufacturer that elects to participate in the NSTOP 
must test, or arrange to be tested, samples collected from their 
gasoline manufacturing facilities as specified in paragraph (c)(2) of 
this section and report results to the independent surveyor within 10 
business days of the date that the sample was collected.
    (b) Program requirements. The NSTOP must meet all the following 
requirements:
    (1) The NSTOP must be planned and conducted by an independent 
surveyor that meets the independence requirements in Sec.  1090.55 and 
the requirements of paragraph (c) of this section.
    (2) The NSTOP must be conducted at each gasoline manufacturing 
facility from all participating gasoline manufacturers.
    (c) Independent surveyor requirements. The independent surveyor 
conducting the NSTOP must meet all the following requirements:
    (1) Submit a proposed NSTOP plan that meets the requirements of 
paragraph (d) of this section to EPA for approval each calendar year.
    (2)(i) Obtain at least one sample representing summer gasoline and 
one sample representing winter gasoline for each participating gasoline 
manufacturing facility. If the fuel manufacturer only produces fuel 
during either the summer or winter season, obtain at least one sample 
during the season that the fuel manufacturer produces fuel.
    (ii)(A) Observe the gasoline manufacturer collect at least one 
sample representing each gasoline required under paragraph (c)(2)(i) of 
this section for each participating gasoline manufacturing facility and 
evaluate whether the gasoline manufacturer collected representative 
sample(s) in accordance with applicable sampling procedures specified in 
Sec.  1090.1335. Immediately notify EPA and the gasoline manufacturer if 
the applicable sampling procedures are not followed.
    (B) The independent surveyor must also obtain a portion of the 
sample collected by the gasoline manufacturer and ship the sample as 
specified in paragraph (c)(2)(v) of this section.
    (C) The observed sample does not need to represent a batch of 
certified

[[Page 613]]

gasoline (i.e., the independent surveyor may observe the collection of a 
simulated sample if the gasoline manufacturer does not have a batch of 
certified gasoline available).
    (iii) The independent surveyor must immediately notify EPA of any 
refusal of a gasoline manufacturer to allow samples to be taken. A 
gasoline manufacturer that refuses to allow the independent surveyor to 
take portions of collected samples is no longer considered by EPA to be 
participating in the NSTOP and must not account for oxygenate added 
downstream under Sec.  1090.710.
    (iv) Samples must be retained by the independent surveyor as 
specified in Sec.  1090.1345(a)(1).
    (v) Samples collected must be shipped via ground service within 2 
business days from when the samples are collected to an EPA-approved 
laboratory as established in an approved plan under this section. A 
random subset of collected samples must also be shipped to the EPA 
National Vehicle and Fuel Emissions Laboratory as established in an 
approved plan under this section.
    (3) Test, or arrange to be tested, samples collected under paragraph 
(c)(2) of this section as follows:
    (i) Winter gasoline samples must be analyzed for oxygenate content, 
sulfur content, benzene content, distillation parameters, aromatics, and 
olefins.
    (ii) Summer gasoline samples must be analyzed for oxygenate content, 
sulfur content, benzene content, distillation parameters, aromatics, 
olefins, and RVP.
    (iii) All samples must be tested by an EPA-approved laboratory using 
test methods specified in subpart N of this part.
    (iv) All analyses must be completed by the EPA-approved laboratory 
within 10 business days after receipt of the sample.
    (v) A gasoline manufacturer must analyze gasoline samples for sulfur 
content, benzene content, and for summer gasoline, RVP.
    (4) Using procedures specified in the EPA-approved plan under this 
section, notify EPA and the gasoline manufacturer within 24 hours after 
the EPA-approved laboratory has completed analysis when any of the 
following occur:
    (i) A test result for a gasoline sample yields a sulfur content that 
exceeds the fuel manufacturing facility gate sulfur per-gallon standard 
in Sec.  1090.205(b).
    (ii) A test result for a gasoline sample yields an RVP that exceeds 
the applicable RVP standard in Sec.  1090.215.
    (5) Make the test results available to EPA and the gasoline 
manufacturer for all analyses specified in paragraph (c)(3) of this 
section within 5 business days of completion of the analysis.
    (6) Compare test results of all samples collected under paragraph 
(c)(2) of this section and all test results obtained from the gasoline 
manufacturer from the same samples as specified in paragraph (a)(3) of 
this section and notify EPA and the gasoline manufacturer if the test 
result for any parameter tested under paragraph (c)(3) of this section 
is greater than the reproducibility of the applicable method specified 
in subpart N of this part.
    (7) Provide quarterly reports to EPA that include the information 
specified in Sec.  1090.925(d).
    (8) Keep records related to the NSTOP as specified in Sec.  
1090.1245(b)(3).
    (9) Submit contracts to EPA as specified in Sec.  1090.1400(b).
    (10) Review the test performance index and precision ratio for each 
method and instrument the laboratory used to test the gasoline samples 
collected under this section as follows:
    (i) For each test method and instrument, the surveyor must obtain 
the relevant records from the gasoline manufacturer to determine the 
site precision, either from an inter-laboratory crosscheck program or 
from ASTM D6299 (incorporated by reference in Sec.  1090.95).
    (ii) Using relevant information obtained from the gasoline 
manufacturers, the surveyor must determine the appropriate Test 
Performance Index (TPI) and Precision Ratio (PR) from Table 2 Guidelines 
for Action Based on TPI in ASTM D6792 (incorporated by reference in 
Sec.  1090.95).
    (iii) A gasoline manufacturer must supply copies of the necessary 
information to the independent surveyor to review the TPI and PR for 
each method

[[Page 614]]

and instrument used to test the gasoline samples collected under this 
section.
    (11) Permit any representative of EPA to monitor at any time the 
conducting of the NSTOP, including sample collection, transportation, 
storage, and analysis.
    (d) NSTOP plan requirements. The NSTOP plan specified in paragraph 
(c)(1) of this section must include, at a minimum, all the following:
    (1) Advance notice of sampling. The NSTOP plan must include 
procedures on how to keep the identification of the gasoline 
manufacturing facilities included in the NSTOP plan confidential with 
minimal advanced notification from any participating gasoline 
manufacturer prior to collecting a sample. However, this information 
must not be kept confidential from EPA.
    (2) Gasoline manufacturing facility selection. (i) Each 
participating gasoline manufacturing facility must be sampled at least 
once during each season they produce fuel. The plan must demonstrate how 
these facilities will be randomly selected within the summer and winter 
seasons.
    (ii) In addition to the summer and winter season samples collected 
at each participating gasoline manufacturing facility, additional 
oversight samples are required under paragraph (d)(3)(ii) of this 
section. The independent surveyor must identify how these samples will 
be randomly distributed among participating gasoline manufacturing 
facilities.
    (3) Number of samples. (i) The number of gasoline manufacturing 
facilities to be sampled must be calculated for the total number of 
samples to be collected for the next calendar year as part of the NSTOP 
plan.
    (ii) The minimum number of samples to be included in the NSTOP plan 
for each calendar year is calculated as follows:

n = R * Fa * Fb * Sun

Where:

n = Minimum number of samples in a year.
R = The number of participating gasoline manufacturing facilities.
Fa = Adjustment factor for the number of extra samples 
          required to compensate for samples that could not be included 
          in the NSTOP (e.g., due to technical or logistical 
          considerations), based on the number of additional samples 
          required during the previous 2 calendar years. Fa 
          must be greater than or equal to 1.1.
Fb = Adjustment factor for the number of samples required to 
          ensure oversight. For purposes of this program, Fb 
          equals 1.25.
Sun = Number of samples required per participating facility 
          per year. For purposes of this program, Sun equals 
          2.

    (4) Laboratory designation. Any laboratory that the independent 
surveyor intends to use to test samples collected as part of the NSTOP 
must be approved annually as part of the program plan approval process 
in Sec.  1090.1400(a). The independent surveyor must include the 
following information regarding each laboratory it intends to use to 
test samples:
    (i) The name of the laboratory.
    (ii) The address of the laboratory.
    (iii) The test methods for each fuel parameter measured at the 
laboratory.
    (iv) Records demonstrating the laboratory's performance in a 
laboratory crosscheck program for the most recent 12 months prior to 
submission of the plan.
    (5) Sampling procedure. The plan must include a detailed description 
of the sampling procedures used to collect samples at participating 
gasoline manufacturing facilities.
    (6) Notification of test results. The NSTOP plan must include a 
description of how the independent surveyor will notify EPA and gasoline 
manufacturers of test results under paragraph (c)(4) of this section.
    (7) Submission. NSTOP plans submitted under this section must be 
approved annually under Sec.  1090.1400(a).



     Subpart P_Retailer and Wholesale Purchaser-Consumer Provisions



Sec.  1090.1500  Overview.

    (a) A retailer or WPC must comply with the labeling requirements in 
Sec. Sec.  1090.1510 and 1090.1515, as applicable, and the refueling 
hardware requirements in Sec. Sec.  1090.1550 through 1090.1565, as 
applicable.
    (b) An alternative label design to those specified in this subpart 
may be used if the design is approved by EPA

[[Page 615]]

prior to use and meets all the following requirements:
    (1) The alternative label must be similar in substance and 
appearance to the EPA-required label.
    (2) The alternative label must contain the same informational 
elements as the EPA-required label.
    (3) The alternative label must be submitted as specified in Sec.  
1090.10.

                                Labeling



Sec.  1090.1510  E15 labeling provisions.

    Any retailer or WPC dispensing E15 must apply a label to the fuel 
dispenser as follows:
    (a) Position the label to clearly identify which control the 
consumer will use to select E15. If the dispenser is set up to dispense 
E15 without the consumer taking action to select the fuel, position the 
label on a vertical surface in a prominent place, approximately at eye 
level.
    (b) Figure 1 of this paragraph shows the required content and 
formatting. Use black letters on an orange background for the lower 
portion and the diagonal ``Attention'' field and use orange letters on a 
black background for the rest of the upper portion. Font size is shown 
in Figure 1. Set vertical position and line spacing as appropriate for 
each field. Dimensions are nominal values.
[GRAPHIC] [TIFF OMITTED] TR04DE20.021



Sec.  1090.1515  Diesel sulfur labeling provisions.

    A retailer or WPC dispensing heating oil, 500 ppm LM diesel fuel, or 
ECA marine fuel must apply labels to fuel dispensers as follows:
    (a) Labels must be in a prominent location where the consumer will 
select or dispense either the corresponding fuel or heating oil. The 
label content must be in block letters of no less than 24-point bold 
type, printed in a color contrasting with the background.
    (b) Labels must include the following statements, or equivalent 
alternative statements approved by EPA:
    (1) For dispensing heating oil along with any kind of diesel fuel 
for any kind of engine, vehicle, or equipment, apply the following 
label:

[[Page 616]]

                               Heating Oil

                                 Warning

    Federal law prohibits use in highway vehicles or engines, or in 
nonroad, locomotive, or marine diesel engines.
    Its use may damage these diesel engines.
    (2) For dispensing 500 ppm LM diesel fuel, apply the following 
label:

       Locomotive and Marine Diesel Fuel (500 ppm Sulfur Maximum)

                                 Warning

    Federal law prohibits use in nonroad engines or in highway vehicles 
or engines.
    (3) For dispensing ECA marine fuel, apply the following label:

               ECA Marine Fuel (1,000 ppm Sulfur Maximum)

    For use in Category 3 (C3) marine vessels only.

                                 Warning

    Federal law prohibits use in any engine that is not installed in a 
C3 marine vessel; use of fuel oil with a sulfur content greater than 
1,000 ppm in an ECA is prohibited except as allowed by 40 CFR part 1043.
    Note: If a pump dispensing 500 ppm LM diesel fuel is labeled with 
the ``LOW SULFUR LOCOMOTIVE AND MARINE DIESEL FUEL (500 ppm Sulfur 
Maximum)'' label, the retailer or WPC does not need to replace this 
label.

                           Refueling Hardware



Sec.  1090.1550  Requirements for gasoline dispensing
nozzles used with motor vehicles.

    The following requirements apply for any nozzle installation used 
for dispensing gasoline into motor vehicles:
    (a) Nozzles must meet the following hardware specifications:
    (1) The outside diameter of the terminal end must not be greater 
than 21.3 mm.
    (2) The terminal end must have a straight section of at least 63 mm.
    (3) The retaining spring must terminate at least 76 mm from the 
terminal end.
    (b) The dispensing flow rate must not exceed a maximum value of 10 
gallons per minute. The flow rate may be controlled through any means in 
the pump/dispenser system, as long as it does not exceed the specified 
maximum value.

[88 FR 4718, Jan. 24, 2023]



Sec.  1090.1555  Requirements for gasoline dispensing nozzles used
primarily with marine vessels.

    The refueling hardware specifications of this section apply for any 
nozzle installation used primarily for dispensing gasoline into marine 
vessels. Note that nozzles meeting these specifications also meet the 
specifications of Sec.  1090.1550(a).
    (a) The outside diameter of the terminal end must have a diameter of 
20.93  00.43 mm.
    (b) The spout must include an aspirator hole for automatic shutoff 
positioned with a center that is 17.0  01.3 mm 
from the terminal end of the spout.
    (c) The terminal end must have a straight section of at least 63.4 
mm with no holes or grooves other than the aspirator hole.
    (d) The retaining spring (if applicable) must terminate at least 76 
mm from the terminal end.



Sec.  1090.1560  Requirements related to dispensing natural gas.

    (a) Except for pumps dedicated to heavy-duty vehicles, any pump 
installation used for dispensing natural gas into motor vehicles must 
have a nozzle and hose configuration that vents no more than 1.2 grams 
of natural gas during a complete refueling event for a vehicle that 
meets the requirements of 40 CFR 86.1813-17(f)(1).
    (b) Determine the amount of natural gas vented using calculations 
based on the geometric shape of the nozzle and hose.



Sec.  1090.1565  Requirements related to dispensing liquefied petroleum gas.

    (a) Except for pumps dedicated to heavy-duty vehicles, any pump 
installation used for dispensing liquefied petroleum gas into motor 
vehicles must have a nozzle that has no greater than 2.0 cm\3\ dead 
space from which liquefied

[[Page 617]]

petroleum gas will be released when the nozzle disconnects from the 
vehicle.
    (b) Determine the volume of the nozzle cavity using calculations 
based on the geometric shape of the nozzle, with an assumed flat surface 
where the nozzle face seals against the vehicle.



               Subpart Q_Importer and Exporter Provisions



Sec.  1090.1600  General provisions for importers.

    (a) This subpart contains provisions that apply to any person who 
imports fuel, fuel additive, or regulated blendstock.
    (b)(1) Except as specified in paragraph (b)(2) of this section, all 
applicable gasoline and diesel standards in subparts C and D of this 
part apply to imported gasoline and diesel.
    (2) A gasoline importer that imports gasoline at multiple import 
facilities must comply with the gasoline average standards in Sec. Sec.  
1090.205(a) and 1090.210(a) as specified in Sec.  1090.705(b), unless 
the importer complies with the provisions of Sec.  1090.1610 to meet the 
alternative per-gallon standards for rail and truck imports specified in 
Sec. Sec.  1090.205(d) and 1090.210(c).
    (c) An importer must separately comply with any applicable 
certification or other requirements for U.S. Customs.
    (d) Alternative testing requirements for an importer that imports 
gasoline or diesel fuel by rail or truck are specified in Sec.  
1090.1610.



Sec.  1090.1605  Importation by marine vessel.

    An importer that imports fuel, fuel additive, or regulated 
blendstock using a marine vessel must comply with the requirements of 
this section.
    (a) The importer must certify each fuel, fuel additive, or regulated 
blendstock imported at each port, unless the fuel is certified at the 
first port of entry in the United States and then transported by the 
same vessel to subsequent ports without picking up additional fuel.
    (b) Except as specified in paragraph (d) of this section, the 
importer must certify each fuel, fuel additive, or regulated blendstock 
while it is on-board the vessel used to transport it to the United 
States. Certification sampling must be performed after the vessel's 
arrival at the port where the fuel, fuel additive, or regulated 
blendstock will be offloaded.
    (1) The importer must sample each compartment of the vessel and use 
one of the following methods to meet testing requirements:
    (i) Treat each compartment as a separate batch.
    (ii) Combine samples from separate compartments into a single, 
vessel volumetric composite sample using the procedures in Section 9.2.4 
of ASTM D4057 (incorporated by reference in Sec.  1090.95). Test results 
from the composite sample are valid only after samples are collected 
from each affected compartment and homogeneity is demonstrated for all 
samples as specified in Sec.  1090.1337.
    (2) The importer must ensure that all applicable per-gallon 
standards are met before offloading the fuel, fuel additive, or 
regulated blendstock.
    (3) The importer must not rely on testing conducted by a foreign 
supplier.
    (c) Once the fuel, fuel additive, or regulated blendstock on a 
vessel has been certified under paragraph (b) of this section, it may be 
transferred to shore tanks using smaller vessels or barges (lightered) 
as a certified fuel, fuel additive, or regulated blendstock. These 
lightering transfers may be to terminals located in any harbor and are 
not restricted to terminals located in the harbor where the vessel is 
anchored. For example, certified gasoline could be transferred from an 
import vessel anchored in New York harbor to a lightering vessel and 
transported to Albany, New York or Providence, Rhode Island without 
separately certifying the gasoline upon arrival in Albany or Providence. 
In this lightering scenario, transfers of certified gasoline to a 
lightering vessel must be accompanied by PTDs that meet the requirements 
of subpart L of this part.
    (d) As an alternative to paragraphs (b) and (c) of this section, the 
importer may offload fuel, fuel additive, or regulated blendstock into 
shore tanks that contain the same fuel, fuel additive, or regulated 
blendstock if the importer meets the following requirements:

[[Page 618]]

    (1) For gasoline, the importer must offload gasoline into one or 
more empty shore tanks or tanks containing PCG that the importer owns.
    (i) If the importer offloads gasoline into one or more empty shore 
tanks, they must sample and test the sulfur content and benzene content, 
and for summer gasoline, RVP, of each shore tank into which the gasoline 
was offloaded.
    (ii) If the importer offloads gasoline into one or more shore tanks 
containing PCG, they must sample the PCG already in the shore tank prior 
to offloading gasoline from the marine vessel, test the sulfur content 
and benzene content, and report this PCG as a negative batch as 
specified in Sec.  1090.905(c)(3)(i). After offloading the gasoline into 
the shore tanks, the importer must sample and test the sulfur content, 
benzene content, and for summer gasoline, RVP, of each shore tank into 
which the gasoline was offloaded and report the volume, sulfur content, 
and benzene content as a positive batch.
    (iii) Include the PCG in the shore tank before offloading and the 
volume and properties after offloading in compliance calculations as 
specified in Sec.  1090.700(d)(4)(i).
    (iv) The sample retention requirements in Sec.  1090.1345 apply to 
the samples taken prior to offloading and those taken after offloading.
    (2) For all other fuel, fuel additive, or regulated blendstock, the 
importer must sample and test the fuel, fuel additive, or regulated 
blendstock in each shore tank into which it was offloaded. The importer 
must ensure that all applicable per-gallon standards are met before the 
fuel, fuel additive, or regulated blendstock is shipped from the shore 
tank.



Sec.  1090.1610  Importation by rail or truck.

    (a) An importer that imports fuel, fuel additive, or regulated 
blendstock by rail or truck must meet the sampling and testing 
requirements of subpart N of this part by sampling and testing each 
compartment of the truck or railcar unless they do one of the following:
    (1) Use supplier results. The importer may rely on test results from 
the supplier for fuel, fuel additive, or regulated blendstock imported 
by rail or truck if the importer meets all the following requirements:
    (i) The importer obtains documentation of test results from the 
supplier for each batch of fuel, fuel additive, or regulated blendstock 
in accordance with the following requirements:
    (A) The testing includes measurements for all the fuel parameters 
specified in Sec.  1090.1310 using the measurement procedures specified 
in Sec.  1090.1350.
    (B) Testing for a given batch occurs after the most recent delivery 
into the supplier's storage tank and before transferring the fuel, fuel 
additive, or regulated blendstock to the railcar or truck.
    (ii) The importer conducts testing to verify test results from each 
supplier as follows:
    (A) Collect a sample at least once every 30 days or every 50 rail or 
truckloads from a given supplier, whichever is more frequent. Test the 
sample as specified in paragraphs (a)(1)(i)(A) and (B) of this section.
    (B) Treat importation of each fuel, fuel additive, or regulated 
blendstock separately, but treat railcars and truckloads together if the 
fuel, fuel additive, or regulated blendstock is imported from a given 
supplier by rail and truck.
    (2) Certify in a storage tank. The importer may transfer the fuel, 
fuel additive, or regulated blendstock imported by rail or truck into 
storage tanks that also contain the same product if the importer meets 
the following requirements:
    (i) For gasoline, the importer transfers gasoline into one or more 
empty tanks or tanks containing PCG that the importer owns.
    (A) If the importer transfers gasoline into one or more empty tanks, 
they must sample and test the sulfur content, benzene content, and for 
summer gasoline, RVP, of each tank into which the gasoline was 
transferred.
    (B) If the importer transfers gasoline into one or more tanks 
containing PCG, they must sample the PCG already in the tank prior to 
transferring gasoline from the truck or train, test

[[Page 619]]

the sulfur content and benzene content, and report this PCG as a 
negative batch as specified in Sec.  1090.905(c)(3)(i). After 
transferring the gasoline into the tanks, the importer must sample and 
test the sulfur content, benzene content, and for summer gasoline, RVP, 
of each tank into which the gasoline was transferred and report the 
volume, sulfur content, and benzene content as a positive batch.
    (C) Include the PCG in the tank before transferring and the volume 
and properties after transferring in compliance calculations as 
specified in Sec.  1090.700(d)(4)(i).
    (D) The sample retention requirements in Sec.  1090.1345 apply to 
the samples taken prior to transferring and those taken after 
transferring.
    (ii) For all other fuel, fuel additive, or regulated blendstock, the 
importer must sample and test the fuel, fuel additive, or regulated 
blendstock in each tank into which it was transferred. The importer must 
ensure that all applicable per-gallon standards are met before the fuel, 
fuel additive, or regulated blendstock is shipped from the tank.
    (b) If an importer that elects to comply with paragraph (a)(1) or 
(2) of this section fails to meet the applicable requirements, they must 
meet the sampling and testing requirements of subpart N of this part for 
each compartment of the truck or railcar until EPA determines that the 
importer has adequately addressed the cause of the failure.



Sec.  1090.1615  Gasoline treated as a blendstock.

    (a) An importer may exclude GTAB from their compliance calculations 
if they meet all the following requirements:
    (1) The importer reports the GTAB to EPA under Sec.  1090.905(c)(7).
    (2) The GTAB is treated as blendstock at a related gasoline 
manufacturing facility that produces gasoline using the GTAB.
    (3) The related gasoline manufacturing facility must report the 
gasoline produced using the GTAB and must include the gasoline produced 
using the GTAB in their compliance calculations.
    (b) After importation, the title of the GTAB must not be transferred 
to another party until the GTAB has been either certified as gasoline 
under subpart K of this part or used to produce gasoline that meets all 
applicable standards and requirements under this part.
    (c) The facility at which the GTAB is used to produce gasoline must 
be physically located at either the same terminal at which the GTAB 
first arrives in the United States, the import facility, or at a 
facility to which the GTAB is directly transported from the import 
facility.
    (d)(1) The importer must treat the GTAB as if it were imported 
gasoline and complete all requirements for a gasoline manufacturer under 
Sec.  1090.105(a) (except for the sampling, testing, and sample 
retention requirements in Sec.  1090.105(a)(6)) for the GTAB at the time 
it is imported.
    (2) Any GTAB that ultimately is not used to produce gasoline (e.g., 
a tank bottom of GTAB) must be treated as newly imported gasoline and 
must meet all applicable requirements for imported gasoline.



Sec.  1090.1650  General provisions for exporters.

    Except as specified in this section and in subpart G of this part, 
fuel produced, imported, distributed, or offered for sale in the United 
States is subject to the standards and requirements of this part.
    (a) Fuel designated for export by a fuel manufacturer is not subject 
to the standards in this part, provided all the requirements in Sec.  
1090.645 are met.
    (b) Fuel not designated for export may be exported without 
restriction. However, the fuel remains subject to the provisions of this 
part while in the United States. For example, fuel designated as ULSD 
must meet the applicable sulfur standards under this part even if it 
will later be exported.
    (c) Fuel that has been classified as American Goods Returned to the 
United States by the U.S. Customs Service under 19 CFR part 10 is not 
considered to be imported for purposes of this part, provided all the 
following requirements are met:

[[Page 620]]

    (1) The fuel was produced at a fuel manufacturing facility located 
within the United States and has not been mixed with fuel produced at a 
fuel manufacturing facility located outside the United States.
    (2) The fuel must be included in compliance calculations by the 
producing fuel manufacturer.
    (3) All the fuel that was exported must ultimately be classified as 
American Goods Returned to the United States and none may be used in a 
foreign country.
    (4) No fuel classified as American Goods Returned to the United 
States may be combined with any fuel produced at a foreign fuel 
manufacturing facility prior to reentry into the United States.



             Subpart R_Compliance and Enforcement Provisions



Sec.  1090.1700  Prohibited acts.

    (a) No person may violate any prohibited act in this part or fail to 
meet a requirement that applies to that person under this part.
    (b) No person may cause another person to commit an act in violation 
of this part.



Sec.  1090.1705  Evidence related to violations.

    (a)(1) EPA may use results from any testing required under this part 
to determine whether a given fuel, fuel additive, or regulated 
blendstock meets any applicable standard. However, EPA may also use any 
other evidence or information to make this determination if the evidence 
or information supports the conclusion that the fuel, fuel additive, or 
regulated blendstock would fail to meet one or more of the parameter 
specifications in this part if the appropriate sampling and testing 
methodology had been correctly performed. Examples of other relevant 
information include business records, commercial documents, and 
measurements with alternative procedures.
    (2) Testing to determine noncompliance with this part may occur at 
any location and be performed by any party.
    (b) Determinations of compliance with the requirements of this part 
other than the fuel, fuel additive, or regulated blendstock standards, 
and determinations of liability for any violation of this part, may be 
based on information from any source or location. Such information may 
include, but is not limited to, business records and commercial 
documents.



Sec.  1090.1710  Penalties.

    (a) Any person liable for a violation under this part is subject to 
civil penalties as specified in 42 U.S.C. 7524 and 7545 for each day of 
such violation and the amount of economic benefit or savings resulting 
from the violation.
    (b)(1) Any person liable for the violation of an average standard 
under this part is subject to a separate day of violation for each day 
in the compliance period.
    (2) Any person liable under this part for a failure to fulfill any 
requirement for credit generation, transfer, use, banking, or deficit 
correction is subject to a separate day of violation for each day in any 
compliance period in which invalid credits are generated, transferred, 
used, or made available for use.
    (c)(1) Any person liable under this part for a violation of a per-
gallon standard, or for causing another party to violate a per-gallon 
standard, is subject to a separate day of violation for each day the 
non-complying fuel, fuel additive, or regulated blendstock remains any 
place in the distribution system.
    (2) For the purposes of paragraph (c)(1) of this section, the length 
of time the fuel, fuel additive, or regulated blendstock that violates a 
per-gallon standard remained in the distribution system is deemed to be 
25 days, unless a person subject to liability or EPA demonstrates by 
reasonably specific showings, by direct or circumstantial evidence, that 
the non-complying fuel, fuel additive, or regulated blendstock remained 
in the distribution system for fewer than or more than 25 days.
    (d) Any person liable for failure to meet, or causing a failure to 
meet, any other provision of this part is liable for a separate day of 
violation for each day such provision remains unfulfilled.

[[Page 621]]

    (e) Failure to meet separate requirements of this part count as 
separate violations.
    (f) Violation of any misfueling prohibition under this part counts 
as a separate violation for each day the noncompliant fuel, fuel 
additive, or regulated blendstock remains in any engine, vehicle, or 
equipment.
    (g) The presumed values of fuel parameters in paragraphs (g)(1) 
through (6) of this section apply for cases in which any person fails to 
comply with the sampling or testing requirements and must be reported, 
unless EPA, in its sole discretion, approves a different value. EPA may 
consider any relevant information to determine whether a different value 
is appropriate.
    (1) For gasoline: 339 ppm sulfur, 1.64 volume percent benzene, and 
11 psi RVP.
    (2) For diesel fuel: 1,000 ppm sulfur.
    (3) For ECA marine fuel: 5,000 ppm sulfur.
    (4) For the PCG portion for PCG by subtraction under Sec.  
1090.1320(a)(1): 0 ppm sulfur and 0 volume percent benzene.
    (5) For fuel additives: 339 ppm sulfur.
    (6) For regulated blendstocks: 339 ppm sulfur and 1.64 volume 
percent benzene.



Sec.  1090.1715  Liability provisions.

    (a) Any person who violates any prohibited act or requirement in 
this part is liable for the violation.
    (b) Any person who causes someone to commit a prohibited act under 
this subpart is liable for violating that prohibition.
    (c) Any parent corporation is liable for any violation committed by 
any of its wholly-owned subsidiaries.
    (d) Each partner to a joint venture, or each owner of a facility 
owned by two or more owners, is jointly and severally liable for any 
violation of this subpart that occurs at the joint venture facility or 
facility owned by the joint owners, or any violation of this part that 
is committed by the joint venture operation or any of the joint owners 
of the facility.
    (e)(1) Any person that produced, imported, sold, offered for sale, 
dispensed, supplied, offered for supply, stored, transported, caused the 
transportation or storage of, or introduced into commerce fuel, fuel 
additive, or regulated blendstock that is in the storage tank containing 
fuel, fuel additive, or regulated blendstock that is found to be in 
violation of a per-gallon standard is liable for the violation.
    (2) In order for a carrier to be liable under paragraph (e)(1) of 
this section, EPA must demonstrate by reasonably specific showing, by 
direct or circumstantial evidence, that the carrier caused the 
violation.
    (f) If a fuel manufacturer's corporate, trade, or brand name is 
displayed at a facility where a violation occurs, the fuel manufacturer 
is liable for the violation. This also applies where the displayed 
corporate, trade, or brand name is from the fuel manufacturer's 
marketing subsidiary.



Sec.  1090.1720  Affirmative defense provisions.

    (a) Any person liable for a violation under Sec.  1090.1715(e) or 
(f) will not be deemed in violation if the person demonstrates all the 
following:
    (1) The violation was not caused by the person or the person's 
employee or agent.
    (2) If PTD requirements of this part apply, the PTDs account for the 
fuel, fuel additive, or regulated blendstock found to be in violation 
and indicate that the violating fuel, fuel additive, or regulated 
blendstock was in compliance with the applicable requirements while in 
that person's control.
    (3) The person conducted a quality assurance program, as specified 
in paragraph (d) of this section.
    (i) A carrier may rely on the quality assurance program carried out 
by another party, including the party that owns the fuel in question, 
provided that the quality assurance program is carried out properly.
    (ii) A retailer or WPC is not required to conduct sampling and 
testing of fuel as part of their quality assurance program.
    (b) For a violation found at a facility operating under the 
corporate, trade, or brand name of a fuel manufacturer, or a fuel 
manufacturer's marketing subsidiary, the fuel manufacturer must show, in 
addition to the defense elements required under paragraph (a) of

[[Page 622]]

this section, that the violation was caused by one of the following:
    (1) An act in violation of law (other than the Clean Air Act or this 
part), or an act of sabotage or vandalism.
    (2) The action of any retailer, distributor, reseller, oxygenate 
blender, carrier, retailer, or WPC in violation of a contractual 
agreement between the branded fuel manufacturer and the person designed 
to prevent such action, and despite periodic sampling and testing by the 
branded fuel manufacturer to ensure compliance with such contractual 
obligation.
    (3) The action of any carrier or other distributor not subject to a 
contract with the fuel manufacturer, but engaged for transportation of 
fuel, fuel additive, or regulated blendstock despite specifications or 
inspections of procedures and equipment that are reasonably calculated 
to prevent such action.
    (c) For any person to show under paragraph (a) of this section that 
a violation was not caused by that person, or to show under paragraph 
(b) of this section that a violation was caused by any of the specified 
actions, the person must demonstrate by reasonably specific showings, 
through direct or circumstantial evidence, that the violation was caused 
or must have been caused by another person and that the person asserting 
the defense did not contribute to that other person's causation.
    (d) To demonstrate an acceptable quality assurance program under 
paragraph (a)(3) of this section, a person must present evidence of all 
the following:
    (1)(i) A periodic sampling and testing program adequately designed 
to ensure the fuel, fuel additive, or regulated blendstock the person 
sold, dispensed, supplied, stored, or transported meets the applicable 
per-gallon standard. A person may meet this requirement by participating 
in the NFSP under Sec.  1090.1405 that was in effect at the time of the 
violation.
    (ii) In addition to the requirements of paragraph (d)(1)(i) of this 
section, a gasoline manufacturer must also participate in the NSTOP 
specified in Sec.  1090.1450 at the time of the violation.
    (2) On each occasion when a fuel, fuel additive, or regulated 
blendstock is found to be in noncompliance with the applicable per-
gallon standard, the person does all the following:
    (i) Immediately ceases selling, offering for sale, dispensing, 
supplying, offering for supply, storing, or transporting the non-
complying fuel, fuel additive, or regulated blendstock.
    (ii) Promptly remedies the violation and the factors that caused the 
violation (e.g., by removing the non-complying fuel, fuel additive, or 
regulated blendstock from the distribution system until the applicable 
standard is achieved and taking steps to prevent future violations of a 
similar nature from occurring).
    (3) For any carrier that transports a fuel, fuel additive, or 
regulated blendstock in a tank truck, the periodic sampling and testing 
program required under paragraph (d)(1) of this section does not need to 
include periodic sampling and testing of gasoline in the tank truck. In 
lieu of such tank truck sampling and testing, the carrier must 
demonstrate evidence of an oversight program for monitoring compliance 
with the requirements of this part relating to the transport or storage 
of the fuel, fuel additive, or regulated blendstock by tank truck, such 
as appropriate guidance to drivers regarding compliance with the 
applicable per-gallon standards and PTD requirements, and the periodic 
review of records received in the ordinary course of business concerning 
gasoline quality and delivery.
    (e) In addition to the defenses provided in paragraphs (a) through 
(d) of this section, in any case in which an oxygenate blender, 
distributor, reseller, carrier, retailer, or WPC would be in violation 
under Sec.  1090.1715 as a result of gasoline that contains between 9 
and 15 percent ethanol (by volume) but exceeds the applicable standard 
by more than 1.0 psi, the oxygenate blender, distributor, reseller, 
carrier, retailer, or WPC will not be deemed in violation if such person 
can demonstrate, by showing receipt of a certification from the facility 
from which the gasoline was received or other evidence acceptable to 
EPA, all the following:

[[Page 623]]

    (1) The gasoline portion of the blend complies with the applicable 
RVP standard in Sec.  1090.215.
    (2) The ethanol portion of the blend does not exceed 15 percent (by 
volume).
    (3) No additional alcohol or other additive has been added to 
increase the RVP of the ethanol portion of the blend.
    (4) In the case of a violation alleged against an oxygenate blender, 
distributor, reseller, or carrier, if the demonstration required by 
paragraphs (e)(1) through (3) of this section is made by a 
certification, it must be supported by evidence that the criteria in 
paragraphs (e)(1) through (3) of this section have been met, such as an 
oversight program conducted by or on behalf of the oxygenate blender, 
distributor, reseller, or carrier alleged to be in violation, which 
includes periodic sampling and testing of the gasoline or monitoring the 
volatility and ethanol content of the gasoline. Such certification will 
be deemed sufficient evidence of compliance provided it is not 
contradicted by specific evidence, such as testing results, and provided 
that the party has no other reasonable basis to believe that the facts 
stated in the certification are inaccurate. In the case of a violation 
alleged against a retail outlet or WPC facility, such certification will 
be deemed an adequate defense for the retailer or WPC, provided that the 
retailer or WPC is able to show certificates for all the gasoline 
contained in the storage tank found in violation, and, provided that the 
retailer or WPC has no reasonable basis to believe that the facts stated 
in the certifications are inaccurate.



                    Subpart S_Attestation Engagements



Sec.  1090.1800  General provisions.

    (a) The following parties must arrange for attestation engagement 
using agreed-upon procedures as specified in this subpart:
    (1) A gasoline manufacturer that produces or imports gasoline 
subject to the requirements of subpart C of this part.
    (2) A gasoline manufacturer that performs testing as specified in 
subpart N of this part or that relies on testing from a third-party 
laboratory.
    (b) An auditor performing attestation engagements must meet the 
following requirements:
    (1) The auditor must meet one of the following professional 
qualifications:
    (i) The auditor may be an internal auditor that is employed by the 
fuel manufacturer and certified by the Institute of Internal Auditors. 
Such an auditor must perform the attestation engagement in accordance 
with the International Standards for the Professional Practice of 
Internal Auditing (Standards) (incorporated by reference in Sec.  
1090.95).
    (ii) The auditor may be a certified public accountant, or firm of 
such accountants, that is independent of the gasoline manufacturer. Such 
an auditor must comply with the AICPA Code of Professional Conduct, 
including its independence requirements, the AICPA Statements on Quality 
Control Standards (SQCS) No. 8, A Firm's System of Quality Control (both 
incorporated by reference in Sec.  1090.95), and applicable rules of 
state boards of public accountancy. Such an auditor must also perform 
the attestation engagement in accordance with the AICPA Statements on 
Standards for Attestation Engagements (SSAE) No. 18, Attestation 
Standards: Clarification and Recodification, especially as noted in 
sections AT-C 105, 215, and 315 (incorporated by reference in Sec.  
1090.95).
    (2) The auditor must meet the independence requirements in Sec.  
1090.55.
    (3) The auditor must be registered with EPA under subpart I of this 
part.
    (4) Any auditor suspended or debarred under 2 CFR part 1532 or 48 
CFR part 9, subpart 9.4, is not qualified to perform attestation 
engagements under this subpart.
    (c) An auditor must perform attestation engagements separately for 
each gasoline manufacturing facility for which the gasoline manufacturer 
submitted reports to EPA under subpart J of this part for the compliance 
period.
    (d) The following provisions apply to each attestation engagement 
performed under this subpart:
    (1) The auditor must prepare a report identifying the applicable 
procedures specified in this subpart along with the auditor's 
corresponding findings for

[[Page 624]]

each procedure. The auditor must submit the report electronically to EPA 
by June 1 of the year following the compliance period.
    (2) The auditor must identify any instances where compared values do 
not agree or where specified values do not meet applicable requirements 
under this part.
    (3) Laboratory analysis refers to the original test result for each 
analysis of a product's properties. The following provisions apply in 
special cases:
    (i) For a laboratory using test methods that must be correlated to 
the standard test method, the laboratory analysis must include the 
correlation factors along with the corresponding test results.
    (ii) For a gasoline manufacturer that relies on a third-party 
laboratory for testing, the laboratory analysis consists of the results 
provided by the third-party laboratory.



Sec.  1090.1805  Representative samples.

    (a) If the specified procedures require evaluation of a 
representative sample from the overall population for a given data set, 
determine the number of results for evaluation using one of the 
following methods:
    (1) Determine sample size using the following table:

         Table 1 to Paragraph (a)(1)--Sample Size Determination
------------------------------------------------------------------------
             Population                           Sample size
------------------------------------------------------------------------
1-25................................  The smaller of the population or
                                       19.
26-40...............................  20.
41-65...............................  25.
66 or more..........................  29.
------------------------------------------------------------------------

    (2) Determine sample size corresponding to a confidence level of 95 
percent, an expected error rate of 0 percent, and a maximum tolerable 
error rate of 10 percent, using conventional statistical principles and 
methods.
    (3) Determine sample size using an alternate method that is 
equivalent to or better than the methods specified in paragraphs (a)(1) 
and (2) of this section with respect to strength of inference and 
freedom from bias. An auditor that determines a sample size using an 
alternate method must describe and justify the alternate method in the 
attestation report.
    (b) Select specific data points for evaluation over the course of 
the compliance period in a way that leads to a simple random sample that 
properly represents the overall population for the data set.



Sec.  1090.1810  General procedures for gasoline manufacturers.

    An auditor must perform the procedures in this section for a 
refiner, blending manufacturer, or transmix processer that produces 
gasoline.
    (a) Registration and EPA reports. An auditor must review 
registration and EPA reports as follows:
    (1) Obtain copies of the gasoline manufacturer's registration 
information submitted under subpart I of this part and all reports 
(except batch reports) submitted under subpart J of this part.
    (2) For each gasoline manufacturing facility, confirm that the 
facility's registration is accurate based on the activities reported 
during the compliance period, including that the registration for the 
facility and any related updates were completed prior to conducting 
regulated activities at the facility and report any discrepancies.
    (3) Confirm that the gasoline manufacturer submitted all the reports 
required under subpart J of this part for activities they performed 
during the compliance period and report any exceptions.
    (4) Obtain a written statement from the gasoline manufacturer's RCO 
that the submitted reports are complete and accurate.
    (5) Report in the attestation report the name of any commercial 
computer program used to track the data required under this part, if 
any.
    (b) Inventory reconciliation analysis. An auditor must perform an 
inventory reconciliation analysis review as follows:
    (1) Obtain an inventory reconciliation analysis from the gasoline 
manufacturer for each product type produced at each facility (e.g., RFG, 
CG, RBOB, CBOB), including the inventory at the beginning and end of the 
compliance period, receipts, production, shipments, transfers, and gain/
loss.
    (2) Foot and cross-foot the volumes.

[[Page 625]]

    (3) Compare the beginning and ending inventory to the manufacturer's 
inventory records for each product type and report any variances.
    (4) Report in the attestation report the volume totals for each 
product type on the basis of which gasoline batches are reported.
    (c) Listing of tenders. An auditor must review a listing of tenders 
as follows:
    (1) Obtain detailed listings of gasoline tenders from the gasoline 
manufacturer, by product type.
    (2) Foot the listings of gasoline tenders.
    (3) Compare the total volume from the gasoline tenders to the total 
volume shipped in the inventory reconciliation analysis for each product 
type and report any variances.
    (d) Listing of batches. An auditor must review listings of batches 
as follows:
    (1) Obtain the batch reports submitted under subpart J of this part.
    (2) Foot the batch volumes by product type.
    (3) Compare the total volume from the batch reports to the total 
production or shipment volume from the inventory reconciliation analysis 
specified in paragraph (b)(4) of this section for each product type and 
report any variances.
    (4) Report as a finding in the attestation report any gasoline batch 
with reported values that do not meet a per-gallon standard in subpart C 
of this part.
    (e) Test methods. An auditor must follow the procedures specified in 
Sec.  1090.1845 to determine whether the gasoline manufacturer complies 
with the applicable quality control requirements specified in Sec.  
1090.1375.
    (f) Detailed testing of BOB tenders. An auditor must review a 
detailed listing of BOB tenders as follows:
    (1) Select a representative sample from the listing of BOB tenders.
    (2) Obtain the associated PTD for each selected sample.
    (3) Using a unique identifier, confirm that the correct PTDs are 
obtained for the samples and compare the volume on the listing of each 
selected BOB tender to the associated PTD and report any exceptions.
    (4) Confirm that the PTD associated with each selected BOB tender 
contains all the applicable language requirements under subpart L of 
this part and report any exceptions.
    (g) Detailed testing of BOB batches. An auditor must review a 
detailed listing of BOB batches as follows:
    (1) Select a representative sample from the BOB batch reports 
submitted under subpart J of this part.
    (2) Obtain the volume documentation and laboratory analysis for each 
selected BOB batch.
    (3) Compare the reported volume for each selected BOB batch to the 
volume documentation and report any exceptions.
    (4) Compare the reported properties for each selected BOB batch to 
the laboratory analysis and report any exceptions.
    (5) Compare the reported test methods used for each selected BOB 
batch to the laboratory analysis and report any exceptions.
    (6) Determine each oxygenate type and amount that is required for 
blending with the BOB.
    (7) Confirm that each oxygenate type and amount included in the BOB 
hand blend agrees with the manufacturer's blending instructions for each 
selected BOB batch and report any exceptions.
    (8) Confirm that the manufacturer participates in the NFSP under 
Sec.  1090.1405, if applicable.
    (9) For a blending manufacturer, confirm that the laboratory 
analysis includes test results for oxygenate content, if applicable, and 
distillation parameters (i.e., T10, T50, T90, final boiling point, and 
percent residue). For a blending manufacturer not required to measure 
oxygenate content, confirm that records demonstrate that the PCG or 
blendstock contained no oxygenate, no oxygenate was added to the final 
gasoline batch, and the blending manufacturer did not account for 
oxygenate added downstream under Sec.  1090.710.
    (h) Detailed testing of finished gasoline tenders. An auditor must 
review a detailed listing of finished gasoline tenders as follows:
    (1) Select a representative sample from the listing of finished 
gasoline tenders.
    (2) Obtain the associated PTD for each selected sample.

[[Page 626]]

    (3) Using a unique identifier, confirm that the correct PTDs are 
obtained for the samples and compare the volume on the listing for each 
finished gasoline tender to the associated PTD and report any 
exceptions.
    (4) Confirm that the PTD associated with each selected finished 
gasoline tender contains all the applicable language requirements under 
subpart L of this part and report any exceptions.
    (i) Detailed testing of finished gasoline batches. An auditor must 
review a detailed listing of finished gasoline batches as follows:
    (1) Select a representative sample of finished gasoline batches from 
the batch reports submitted under subpart J of this part.
    (2) Obtain the volume documentation and laboratory analysis for each 
selected finished gasoline batch.
    (3) Compare the reported volume for each selected finished gasoline 
batch to the volume documentation and report any exceptions.
    (4) Compare the reported properties for each selected finished 
gasoline batch to the laboratory analysis and report any exceptions.
    (5) Compare the reported test methods used for each selected 
finished gasoline batch to the laboratory analysis and report any 
exceptions.
    (6) For a blending manufacturer, confirm that the laboratory 
analysis includes test results for oxygenate content, if applicable, and 
distillation parameters (i.e., T10, T50, T90, final boiling point, and 
percent residue). For a blending manufacturer not required to measure 
oxygenate content, confirm that records demonstrate that the PCG or 
blendstock contained no oxygenate, no oxygenate was added to the final 
gasoline batch, and the blending manufacturer did not account for 
oxygenate added downstream under Sec.  1090.710.
    (j) Detailed testing of blendstock batches. In the case of adding 
blendstock to TGP or PCG under Sec.  1090.1320(a)(2), an auditor must 
review a detailed listing of blendstock batches as follows:
    (1) Select a representative sample of blendstock batches from the 
batch reports submitted under subpart J of this part.
    (2) Obtain the volume documentation and the laboratory analysis for 
each selected blendstock batch.
    (3) Compare the reported volume for each selected blendstock batch 
to the volume documentation and report any exceptions.
    (4) Compare the reported properties for each selected blendstock 
batch to the laboratory analysis and report any exceptions.
    (5) Compare the reported test methods used for each selected 
blendstock batch to the laboratory analysis and report any exceptions.
    (6) For blending a manufacturer not required to measure oxygenate 
content, confirm that records demonstrate that the PCG or blendstock 
contained no oxygenate, no oxygenate was added to the final gasoline 
batch, and the blending manufacturer did not account for oxygenate added 
downstream under Sec.  1090.710.



Sec.  1090.1815  General procedures for gasoline importers.

    An auditor must perform the procedures in this section for a 
gasoline importer.
    (a) Registration and EPA reports. An auditor must review 
registration and EPA reports for a gasoline importer as specified in 
Sec.  1090.1810(a).
    (b) Listing of imports. An auditor must review a listing of imports 
as follows:
    (1) Obtain detailed listings of gasoline imports from the importer, 
by product type.
    (2) Foot the listings of gasoline imports from the importer.
    (3) Obtain listings of gasoline imports directly from the third-
party customs broker, by product type.
    (4) Foot the listings of gasoline imports from the third-party 
customs broker.
    (5) Compare the total volume from the importer's listings of 
gasoline imports to the listings from the third-party customs broker for 
each product type and report any variances.
    (6) Report in the attestation report the total imported volume for 
each product type.
    (c) Listing of batches. An auditor must review listings of batches 
as follows:
    (1) Obtain the batch reports submitted under subpart J of this part.

[[Page 627]]

    (2) Foot the batch volumes by product type.
    (3) Compare the total volume from the batch reports to the total 
volume per the listings of gasoline imports obtained under paragraph 
(b)(1) of this section for each product type and report any variances.
    (4) Report as a finding in the attestation report any gasoline 
batches with parameter results that do not meet the per-gallon standards 
in subpart C of this part.
    (d) Test methods. An auditor must follow the procedures specified in 
Sec.  1090.1845 to determine whether the importer complies with the 
quality control requirements specified in Sec.  1090.1375 for gasoline, 
gasoline additives, and gasoline regulated blendstocks.
    (e) Detailed testing of BOB imports. An auditor must review a 
detailed listing of BOB imports as follows:
    (1) Select a representative sample from the listing of BOB imports 
from the importer and obtain the associated U.S. Customs Entry Summary 
and PTD for each selected BOB import.
    (2) Using a unique identifier, confirm that the correct U.S. Customs 
Entry Summaries are obtained for the samples and compare the location 
that each selected BOB import arrived in the United States and volume on 
the listing of BOB imports from the importer to the U.S. Customs Entry 
Summary and report any exceptions.
    (3) Using a unique identifier, confirm that the correct PTDs are 
obtained for the samples. Confirm that the PTD contains all the 
applicable language requirements under subpart L of this part and report 
any exceptions.
    (f) Detailed testing of BOB batches. An auditor must review a 
detailed listing of BOB batches as follows:
    (1) Select a representative sample of BOB batches from the batch 
reports submitted under subpart J of this part and obtain the volume 
inspection report and laboratory analysis for each selected BOB batch.
    (2) Compare the reported volume for each selected BOB batch to the 
volume inspection report and report any exceptions.
    (3) Compare the reported properties for each selected BOB batch to 
the laboratory analysis and report any exceptions.
    (4) Compare the reported test methods used for each selected BOB 
batch to the laboratory analysis and report any exceptions.
    (5) Determine each oxygenate type and amount that is required for 
blending with each selected BOB batch.
    (6) Confirm that each oxygenate type and amount included in the BOB 
hand blend agrees within an acceptable range to each selected BOB batch 
and report any exceptions.
    (7) Confirm that the importer participates in the NFSP under Sec.  
1090.1405, if applicable.
    (g) Detailed testing of finished gasoline imports. An auditor must 
review a detailed listing of finished gasoline imports as follows:
    (1) Select a representative sample from the listing of finished 
gasoline imports from the importer and obtain the associated U.S. 
Customs Entry Summary and PTD for each selected finished gasoline 
import.
    (2) Using a unique identifier, confirm that the correct U.S. Customs 
Entry Summaries are obtained for the samples and compare the location 
that each selected finished gasoline import arrived in the United States 
and volume on the listing of finished gasoline imports from the importer 
to the U.S. Customs Entry Summary and report any exceptions.
    (3) Using a unique identifier, confirm that the correct PTDs are 
obtained for the samples. Confirm that the PTD contain all the 
applicable language requirements under subpart L of this part and report 
any exceptions.
    (h) Detailed testing of finished gasoline batches. An auditor must 
review a detailed listing of finished gasoline batches as follows:
    (1) Select a representative sample of finished gasoline batches from 
the batch reports submitted under subpart J of this part and obtain the 
volume inspection report and laboratory analysis for each selected 
finished gasoline batch.
    (2) Compare the reported volume for each selected finished gasoline 
batch to the volume inspection report and report any exceptions.

[[Page 628]]

    (3) Compare the reported properties for each selected finished 
gasoline batch to the laboratory analysis and report any exceptions.
    (4) Compare the reported test methods used for each selected 
finished gasoline batch to the laboratory analysis and report any 
exceptions.
    (i) Additional procedures for certain gasoline imported by rail or 
truck. An auditor must perform the following additional procedures for 
an importer that imports gasoline into the United States by rail or 
truck under Sec.  1090.1610:
    (1) Select a representative sample from the listing of batches 
obtained under paragraph (c)(1) of this section and perform the 
following for each selected batch:
    (i) Identify the point of sampling and testing associated with each 
selected batch in the tank activity records from the supplier.
    (ii) Confirm that the sampling and testing occurred after the most 
recent delivery into the supplier's storage tank and before transferring 
product to the railcar or truck.
    (2)(i) Obtain a detailed listing of the importer's quality assurance 
program sampling and testing results.
    (ii) Determine whether the frequency of the sampling and testing 
meets the requirements in Sec.  1090.1610(a)(2).
    (iii) Select a representative sample from the importer's sampling 
and testing records under the quality assurance program and perform the 
following for each selected batch:
    (A) Obtain the corresponding laboratory analysis.
    (B) Determine whether the importer analyzed the test sample, and 
whether they performed the analysis using the methods specified in 
subpart N of this part.
    (C) Review the terminal test results corresponding to the time of 
collecting the quality assurance test samples. Compare the terminal test 
results with the test results from the quality assurance program, noting 
any parameters with differences that are greater than the 
reproducibility of the applicable method specified in subpart N of this 
part.



Sec.  1090.1820  Additional procedures for gasoline treated as blendstock.

    In addition to any applicable procedures required under Sec. Sec.  
1090.1810 and 1090.1815, an auditor must perform the procedures in this 
section for a gasoline manufacturer that imports GTAB under Sec.  
1090.1615.
    (a) Listing of GTAB imports. An auditor must review a listing of 
GTAB imports as follows:
    (1) Obtain a detailed listing of GTAB imports from the GTAB 
importer.
    (2) Foot the listing of GTAB imports from the GTAB importer.
    (3) Obtain a listing of GTAB imports directly from the third-party 
customs broker.
    (4) Foot the listing of GTAB imports from the third-party customs 
broker and report any variances.
    (5) Compare the total volume from the GTAB importer's listing of 
GTAB imports to the listing from the third-party customs broker.
    (6) Report in the attestation report the total imported volume of 
GTAB and the corresponding facilities at which the GTAB was blended.
    (b) Listing of GTAB batches. An auditor must review a listing of 
GTAB batches as follows:
    (1) Obtain the GTAB batch reports submitted under subpart J of this 
part.
    (2) Foot the batch volumes.
    (3) Compare the total volume from the GTAB batch reports to the 
total volume from the listing of GTAB imports in paragraph (a)(6) of 
this section and report any variances.
    (c) Detailed testing of GTAB imports. An auditor must review a 
detailed listing of GTAB imports as follows:
    (1) Select a representative sample from the listing of GTAB imports 
obtained under paragraph (a)(1) of this section.
    (2) For each selected GTAB batch, obtain the U.S. Customs Entry 
Summaries.
    (3) Using a unique identifier, confirm that the correct U.S. Customs 
Entry Summaries are obtained for the samples. Compare the volumes and 
locations that each selected GTAB batch arrived in the United States to 
the U.S. Customs Entry Summary and report any exceptions.

[[Page 629]]

    (d) Detailed testing of GTAB batches. An auditor must review a 
detailed listing of GTAB batches as follows:
    (1) Select a representative sample from the GTAB batch reports 
obtained under paragraph (b)(1) of this section.
    (2) For each selected GTAB batch sample, obtain the volume 
inspection report.
    (3) Compare the reported volume for each selected GTAB batch to the 
volume inspection report and report any exceptions.
    (e) GTAB tracing. An auditor must trace and review the movement of 
GTAB from importation to gasoline production as follows:
    (1) Compare the volume total on each GTAB batch report obtained 
under paragraph (b)(1) of this section to the GTAB volume total in the 
gasoline manufacturer's inventory reconciliation analysis under Sec.  
1090.1810(b).
    (2) For each selected GTAB batch under paragraph (d)(1) of this 
section:
    (i) Obtain tank activity records that describe the movement of each 
selected GTAB batch from importation to gasoline production.
    (ii) Identify each selected GTAB batch in the tank activity records 
and trace each selected GTAB batch to subsequent reported batches of BOB 
or finished gasoline.
    (iii) Match the location of the facility where gasoline was produced 
from each selected GTAB batch to the location where each selected GTAB 
batch arrived in the United States, or to the facility directly 
receiving the GTAB batch from the import facility.
    (iv) Determine the status of the tank(s) before receiving each 
selected GTAB batch (e.g., empty tank, tank containing blendstock, tank 
containing GTAB, tank containing PCG).
    (v) If the tank(s) contained PCG before receiving the selected GTAB 
batch, take the following additional steps:
    (A) Obtain and review a copy of the documented tank mixing 
procedures.
    (B) Determine the volume and properties of the tank bottom that was 
PCG before adding GTAB.
    (C) Confirm that the gasoline manufacturer determined the volume and 
properties of the BOB or finished gasoline produced using GTAB by 
excluding the volume and properties of any PCG, and that the gasoline 
manufacturer separately reported the PCG volume and properties under 
subpart J of this part and report any discrepancies.



Sec.  1090.1825  Additional procedures for PCG used to produce gasoline.

    In addition to any applicable procedures required under Sec.  
1090.1810, an auditor must perform the procedures in this section for a 
gasoline manufacturer that produces gasoline from PCG under Sec.  
1090.1320.
    (a) Listing of PCG batches. An auditor must review a listing of PCG 
batches as follows:
    (1) Obtain the PCG batch reports submitted under subpart J of this 
part.
    (2) Foot the batch volumes.
    (3) Compare the volume total for each PCG batch report to the 
receipt volume total in the inventory reconciliation analysis specified 
in Sec.  1090.1810(b) and report any variances.
    (b) Detailed testing of PCG batches. An auditor must review a 
detailed listing of PCG batches as follows:
    (1) Select a representative sample from the PCG batch reports 
obtained under paragraph (a)(1) of this section.
    (2) Obtain the volume documentation, laboratory analysis, associated 
PTDs, and tank activity records for each selected PCG batch.
    (3) Identify each selected PCG batch in the tank activity records 
and trace each selected PCG batch to subsequent reported batches of BOB 
or finished gasoline and report any exceptions.
    (4) For each selected PCG batch, report as a finding in the 
attestation report any instances where the reported PCG batch volume was 
adjusted from the original receipt volume, such as for exported PCG.
    (5) Compare the volume for each selected PCG batch to the volume 
documentation and report any exceptions.
    (6) Compare the product type and grade for each selected PCG batch 
to the associated PTDs and report any exceptions.
    (7) Compare the reported properties for each selected PCG batch to 
the laboratory analysis and report any exceptions.
    (8) Compare the reported test methods used for each selected PCG 
batch to

[[Page 630]]

the laboratory analysis and report any exceptions.



Sec.  1090.1830  Alternative procedures for certified butane blenders.

    An auditor must use the procedures in this section instead of or in 
addition to the applicable procedures in Sec.  1090.1810 for a certified 
butane blender that blends certified butane into PCG under Sec.  
1090.1320(b).
    (a) Registration and EPA reports. An auditor must review 
registration and EPA reports as follows:
    (1) Obtain copies of the certified butane blender's registration 
information submitted under subpart I of this part and all reports 
submitted under subpart J of this part, including the batch reports for 
the butane received and blended.
    (2) For each butane blending facility, confirm that the facility's 
registration is accurate based on activities reported during the 
compliance period, including that the registration for the facility and 
any related updates were completed prior to conducting regulated 
activities at the facility and report any discrepancies.
    (3) Confirm that the certified butane blender submitted the reports 
required under subpart J of this part for activities they performed 
during the compliance period and report any exceptions.
    (4) Obtain a written statement from the certified butane blender's 
RCO that the submitted reports are complete and accurate.
    (5) Report in the attestation report the name of any commercial 
computer program used to track the data required under this part, if 
any.
    (b) Inventory reconciliation analysis. An auditor must perform an 
inventory reconciliation analysis review as follows:
    (1) Obtain an inventory reconciliation analysis from the certified 
butane blender for each butane blending facility related to all 
certified butane movements, including the inventory at the beginning and 
end of the compliance period, receipts, blending/production volumes, 
shipments, transfers, and gain/loss.
    (2) Foot and cross-foot the volumes.
    (3) Compare the beginning and ending inventory to the certified 
butane blender's inventory records and report any variances.
    (4) Compare the total volume of certified butane received from the 
batch reports obtained under paragraph (a)(1) of this section to the 
inventory reconciliation analysis and report any variances.
    (5) Compare the total volume of certified butane blended from the 
batch reports to the inventory reconciliation analysis and report any 
variances.
    (6) Report in the attestation report the total volume of certified 
butane received and blended.
    (c) Listing of certified butane receipts. An auditor must review a 
listing of certified butane receipts as follows:
    (1) Obtain a detailed listing of all certified butane batches 
received at the butane blending facility from the certified butane 
blender.
    (2) Foot the listing of certified butane batches received.
    (3) Compare the total volume from batch reports for certified butane 
received at the butane blending facility to the certified butane 
blender's listing of certified butane batches received and report any 
variances.
    (d) Detailed testing of certified butane batches. An auditor must 
review a detailed listing of certified butane batches as follows:
    (1) Select a representative sample from the certified butane batch 
reports submitted under subpart J of this part.
    (2) Obtain the volume documentation and laboratory analysis for each 
selected certified butane batch.
    (3) Compare the reported volume for each selected certified butane 
batch to the volume documentation and report any exceptions.
    (4) Compare the reported properties for each selected certified 
butane batch to the laboratory analysis and report any exceptions.
    (5) Compare the reported test methods used for each selected 
certified butane batch to the laboratory analysis and report any 
exceptions.
    (6) Confirm that the butane meets the standards for certified butane 
under subpart C of this part and report any exceptions.
    (e) Quality control review. An auditor must obtain the certified 
butane blender's sampling and testing results for

[[Page 631]]

certified butane received and determine if the frequency of the sampling 
and testing meets the requirements in Sec.  1090.1320(b)(4) and report 
any discrepancies.



Sec.  1090.1835  Alternative procedures for certified pentane blenders.

    (a) An auditor must use the procedures in this section instead of or 
in addition to the applicable procedures in Sec.  1090.1810 for a 
certified pentane blender that blends certified pentane into PCG under 
Sec.  1090.1320(b).
    (b) An auditor must apply the procedures in Sec.  1090.1830 by 
substituting ``pentane'' for ``butane'' in all cases.



Sec.  1090.1840  Additional procedures related to compliance
with gasoline average standards.

    An auditor must perform the procedures in this section for a 
gasoline manufacturer that complies with the standards in subpart C of 
this part using the procedures specified in subpart H of this part.
    (a) Annual compliance demonstration review. An auditor must review 
annual compliance demonstrations as follows:
    (1) Obtain the annual compliance reports for sulfur and benzene and 
associated batch reports submitted under subpart J of this part.
    (2)(i) For a gasoline refiner or blending manufacturer, compare the 
gasoline production volume from the annual compliance report to the 
inventory reconciliation analysis under Sec.  1090.1810(b) and report 
any variances.
    (ii) For a gasoline importer, compare the gasoline import volume 
from the annual compliance report to the corresponding volume from the 
listing of imports under Sec.  1090.1815(b) and report any variances.
    (3) For each facility, recalculate the following and report in the 
attestation report the recalculated values:
    (i) Compliance sulfur value, per Sec.  1090.700(a)(1), and 
compliance benzene value, per Sec.  1090.700(b)(1)(i).
    (ii) Unadjusted average sulfur concentration, per Sec.  1090.745(b), 
and average benzene concentration, per Sec.  1090.700(b)(3).
    (iii) Number of credits generated during the compliance period, or 
number of banked or traded credits needed to meet standards for the 
compliance period.
    (iv) Number of credits from the preceding compliance period that are 
expired or otherwise no longer available for the compliance period being 
reviewed.
    (v) Net average sulfur concentration, per Sec.  1090.745(c), and net 
average benzene concentration, per Sec.  1090.745(d).
    (4) Compare the recalculated values in paragraph (a)(3) of this 
section to the reported values in the annual compliance reports and 
report any exceptions.
    (5) Report in the attestation report whether the gasoline 
manufacturer had a deficit for both the compliance period being reviewed 
and the preceding compliance period.
    (b) Credit transaction review. An auditor must review credit 
transactions as follows:
    (1) Obtain the gasoline manufacturer's credit transaction reports 
submitted under subpart J of this part and contracts or other 
information that documents all credit transfers. Also obtain records 
that support intracompany transfers.
    (2) For each reported transaction, compare the supporting 
documentation with the credit transaction reports for the following 
elements and report any exceptions:
    (i) Compliance period of creation.
    (ii) Credit type (i.e., sulfur or benzene) and number of times 
traded.
    (iii) Quantity.
    (iv) The name of the other company participating in the credit 
transfer.
    (v) Transaction type.
    (c) Facility-level credit reconciliation. An auditor must perform a 
facility-level credit reconciliation separately for each gasoline 
manufacturing facility as follows:
    (1) Obtain the credits remaining or the credit deficit from the 
previous compliance period from the gasoline manufacturer's credit 
transaction information for the previous compliance period.
    (2) Compute and report as a finding the net credits remaining at the 
end of the compliance period.
    (3) Compare the ending balance of credits or credit deficit 
recalculated in paragraph (c)(2) of this section to the

[[Page 632]]

corresponding value from the annual compliance report and report any 
variances.
    (4) For an importer, the procedures of this paragraph (c) apply at 
the company level.
    (d) Company-level credit reconciliation. An auditor must perform a 
company-level credit reconciliation as follows:
    (1) Obtain a credit reconciliation listing company-wide credits 
aggregated by facility for the compliance period.
    (2) Foot and cross-foot the credit quantities.
    (3) Compare and report the beginning balance of credits, the ending 
balance of credits, the associated credit activity at the company level 
in accordance with the credit reconciliation listing, and the 
corresponding credit balances and activity submitted under subpart J of 
this part.
    (e) Procedures for gasoline manufacturers that recertify BOB. An 
auditor must perform the following procedures for a gasoline 
manufacturer that recertifies a BOB under Sec.  1090.740 and incurs a 
deficit:
    (1) Perform the procedures specified in Sec.  1090.1810(a) to review 
registration and EPA reports.
    (2) Obtain the batch reports for recertified BOB submitted under 
subpart J of this part.
    (3) Select a representative sample of recertified BOB batches from 
the batch reports.
    (4) For each sample, obtain supporting documentation.
    (5) Confirm the accuracy of the information reported and report any 
exceptions.
    (6) Recalculate the deficits in accordance with the provisions of 
Sec.  1090.740 and report any discrepancies.
    (7) Confirm that the deficits are included in the annual compliance 
demonstration calculations and report any exceptions.



Sec.  1090.1845  Procedures related to meeting performance-based 
measurement and statistical quality control for test methods.

    (a) General provisions. (1) An auditor must conduct the procedures 
specified in this section for a gasoline manufacturer.
    (2) An auditor performing the procedures specified in this section 
must meet the laboratory experience requirements specified in Sec.  
1090.55(b)(2).
    (3) In cases where the auditor employs, contracts, or subcontracts 
an external specialist, all the requirements in Sec.  1090.55 apply to 
the external specialist. The auditor is responsible for overseeing the 
work of the specialist, consistent with applicable professional 
standards specified in Sec.  1090.1800.
    (4) In the case of quality control testing at a third-party 
laboratory, the auditor may perform a single attestation engagement on 
the third-party laboratory for multiple gasoline manufacturers if the 
auditor directly reviewed the information from the third-party 
laboratory. A third-party laboratory may also arrange for an auditor to 
perform a single attestation engagement on the third-party laboratory 
and make that available to gasoline manufacturers that have testing 
performed by the third-party laboratory.
    (b) Non-referee method qualification review. For each test method 
used to measure a parameter for gasoline as specified in a report 
submitted under subpart J of this part that is not one of the referee 
procedures listed in Sec.  1090.1360(d), the auditor must review the 
following:
    (1) Obtain supporting documentation showing that the laboratory has 
qualified the test method by meeting the precision and accuracy criteria 
specified under Sec.  1090.1365.
    (2) Report in the attestation report a list of the alternative 
methods used.
    (3) Confirm that the gasoline manufacturer supplied the supporting 
documentation for each test method specified in paragraph (b)(1) of this 
section and report any exceptions.
    (4) If an auditor has previously reviewed supporting documentation 
under this paragraph (b) for an alternative method at the facility, the 
auditor does not have to review the supporting document again.
    (c) Reference installation review. For each reference installation 
used by the gasoline manufacturer during the compliance period, the 
auditor must review the following:
    (1) Obtain supporting documentation demonstrating that the reference 
installation followed the qualification procedures specified in Sec.  
1090.1370(c)(1)

[[Page 633]]

and (2) and the quality control procedures specified in Sec.  
1090.1370(c)(3).
    (2) Confirm that the facility completed the qualification procedures 
and report any exceptions.
    (d) Instrument control review. For each test instrument used to test 
gasoline parameters for batches selected as part of a representative 
sample under Sec.  1090.1810, the auditor must review whether test 
instruments were in control as follows:
    (1) Obtain a listing from the laboratory of the instruments and 
period when the instruments were used to measure gasoline parameters 
during the compliance period for batches selected as part of the 
representative sample under Sec.  1090.1810.
    (2) Obtain statistical quality assurance data and control charts 
demonstrating ongoing quality testing to meet the accuracy and precision 
requirements specified in Sec.  1090.1375 or 40 CFR 80.47, as 
applicable.
    (3) Confirm that the facility performed statistical quality 
assurance monitoring of its instruments under Sec.  1090.1375 and report 
any exceptions.
    (4) Report as a finding in the attestation report the instrument 
lists obtained under paragraph (d)(1) of this section and the compliance 
period when the instrument control review was completed.



Sec.  1090.1850  Procedures related to in-line blending waivers.

    In addition to any other procedure required under this subpart, an 
auditor must perform the procedures specified in this section for a 
gasoline manufacturer that relies on an in-line blending waiver under 
Sec.  1090.1315.
    (a) Obtain a copy of the gasoline manufacturer's in-line blending 
waiver submission and EPA's approval letter.
    (b) Confirm that the sampling procedures and composite calculations 
conform to specifications as specified in Sec.  1090.1315(a)(2).
    (c) Review the gasoline manufacturer's procedure for defining a 
batch for compliance purposes. Review available test data demonstrating 
that the test results from in-line blending correctly characterize the 
fuel parameters for the designated batch.
    (d) Confirm that the gasoline manufacturer corrected their 
operations because of previous audits, if applicable.
    (e) Confirm that the equipment and procedures are not materially 
changed from the gasoline manufacturer's in-line blending waiver. In 
cases of material change in equipment or procedure, confirm that the 
gasoline manufacturer updated their in-line blending waiver and report 
any exceptions.
    (f) Perform any additional procedures unique to the blending 
operation, as specified in the in-line blending waiver, and report any 
findings, variances, or exceptions, as applicable.
    (g) Confirm that the gasoline manufacturer has complied with all 
provisions related to their in-line blending waiver and report any 
exceptions.

                       PARTS 1091	1099 [RESERVED]

[[Page 635]]



  CHAPTER IV--ENVIRONMENTAL PROTECTION AGENCY AND DEPARTMENT OF JUSTICE




  --------------------------------------------------------------------

     SUBCHAPTER A--ACCIDENTAL RELEASE PREVENTION REQUIREMENTS; RISK 
     MANAGEMENT PROGRAMS UNDER THE CLEAN AIR ACT SECTION 112(R)(7); 
        DISTRIBUTION OF OFF-SITE CONSEQUENCE ANALYSIS INFORMATION
Part                                                                Page
1400            Distribution of off-site consequence 
                    analysis information....................         637
1401-1499

 [Reserved]

[[Page 637]]



SUBCHAPTER A_ACCIDENTAL RELEASE PREVENTION REQUIREMENTS; RISK MANAGEMENT 
PROGRAMS UNDER THE CLEAN AIR ACT SECTION 112(r)(7); DISTRIBUTION OF OFF-
                  SITE CONSEQUENCE ANALYSIS INFORMATION





PART 1400_DISTRIBUTION OF OFF-SITE CONSEQUENCE ANALYSIS 
INFORMATION--Table of Contents



                            Subpart A_General

Sec.
1400.1 Purpose.
1400.2 Definitions.

                         Subpart B_Public Access

1400.3 Public access to paper copies of off-site consequence analysis 
          information.
1400.4 Vulnerable zone indicator system.
1400.5 Internet access to certain off-site consequence analysis data 
          elements.
1400.6 Enhanced local access.

    Subpart C_Access to Off-Site Consequence Analysis Information by 
                          Government Officials

1400.7 In general.
1400.8 Access to off-site consequence analysis information by Federal 
          Government officials.
1400.9 Access to off-site consequence analysis information by State and 
          local government officials.

                       Subpart D_Other Provisions

1400.10 Limitation on public dissemination.
1400.11 Limitation on dissemination to State and local government 
          officials.
1400.12 Qualified researchers.
1400.13 Read-only database.

    Authority: 42 U.S.C. 7412(r)(7)(H)(ii).

    Source: 65 FR 48131, Aug. 4, 2000, unless otherwise noted.



                            Subpart A_General



Sec.  1400.1  Purpose.

    Stationary sources subject to the Chemical Accident Prevention 
Provisions of 40 CFR part 68 are required to analyze the potential harm 
to public health and welfare of hypothetical chemical accidents and 
submit the results of their analyses to the U.S. Environmental 
Protection Agency as part of risk management plans. This part governs 
access by the public and by government officials to the portions of risk 
management plans containing the results of those analyses and certain 
related materials. This part also restricts dissemination of that 
information by government officials.



Sec.  1400.2  Definitions.

    For the purposes of this part:
    (a) Accidental release means an unanticipated emission of a 
regulated substance or other extremely hazardous substance into the 
ambient air from a stationary source.
    (b) Administrator means the Administrator of the U.S. Environmental 
Protection Agency or his or her designated representative.
    (c) Attorney General means the Attorney General of the United States 
or his or her designated representative.
    (d) Federal government official means--
    (1) An officer or employee of the United States; and
    (2) An officer or employee of an agent or contractor of the Federal 
government.
    (e) State or local government official means--
    (1) An officer or employee of a State or local government;
    (2) An officer or employee of an agent or contractor of a State or 
local government;
    (3) An individual affiliated with an entity that has been given, by 
a state or local government, responsibility for preventing, planning 
for, or responding to accidental releases, such as a member of a Local 
Emergency Planning Committee (LEPC) or a State Emergency Response 
Commission (SERC), or a paid or volunteer member of a fire or police 
department; or
    (4) An officer or employee or an agent or contractor of an entity 
described in paragraph (e)(3) of this section.
    (f) LEPC means a Local Emergency Planning Committee created under 
the Emergency Planning and Community Right-to-Know Act, 42 U.S.C. 11001 
et seq.

[[Page 638]]

    (g) Member of the public or person means an individual.
    (h) Official use means an action of a Federal, State, or local 
government agency or an entity described in paragraph (e)(3) of this 
section intended to carry out a function relevant to preventing, 
planning for, or responding to accidental releases.
    (i) Off-site consequence analysis (OCA) information means sections 2 
through 5 of a risk management plan (consisting of an evaluation of one 
or more worst-case release scenarios or alternative release scenarios) 
for an identified facility and any electronic database created by the 
Administrator from those sections.
    (j) Off-site consequence analysis (OCA) data elements means the 
results of the off-site consequence analysis conducted by a stationary 
source pursuant to 40 CFR part 68, subpart B, when presented in a format 
different than sections 2 through 5 of a risk management plan or any 
Administrator-created electronic database.
    (k) Off-site consequence analysis (OCA) rankings means any statewide 
or national rankings of identified stationary sources derived from OCA 
information.
    (l) Qualified researcher means a researcher who receives OCA 
information pursuant to 42 U.S.C. 7412(r)(7)(H)(vii).
    (m) Related local government agencies means local government 
agencies, such as police, fire, emergency management, and planning 
departments, that are involved in chemical emergency planning, 
prevention, or response.
    (n) Related state government agencies means State government 
agencies, such as emergency management, environmental protection, 
health, and natural resources departments, that are involved in chemical 
emergency planning, prevention, or response.
    (o) Risk management plan (RMP) means a risk management plan 
submitted to the Administrator by an owner or operator of a stationary 
source pursuant to 40 CFR part 68, subpart G.
    (p) SERC means a State Emergency Response Commission created under 
the Emergency Planning and Community Right-to-Know Act, 42 U.S.C. 11001 
et seq.
    (q) State has the same meaning as provided in 42 U.S.C. 7602(d) (a 
state, the District of Columbia, the Commonwealth of Puerto Rico, the 
Virgin Islands, Guam, American Samoa, and the Commonwealth of the 
Northern Mariana Islands).
    (r) Stationary source has the same meaning as provided in 40 CFR 
part 68 subpart A, Sec.  68.3.
    (s) Vulnerable zone means the geographical area that could be 
affected by a worst-case or alternative scenario release from a 
stationary source, as indicated by the off-site consequence analysis 
reported by the stationary source in its risk management plan pursuant 
to the applicable requirements of 40 CFR Part 68. It is defined as a 
circle, the center of which is the stationary source and the radius of 
which is the ``distance-to-endpoint,'' or the distance a toxic or 
flammable cloud, overpressure, or radiant heat would travel after being 
released and before dissipating to the point that it no longer threatens 
serious short-term harm to people or the environment.



                         Subpart B_Public Access



Sec.  1400.3  Public access to paper copies of off-site consequence analysis information.

    (a) General. The Administrator and the Attorney General shall ensure 
that any member of the public has access to a paper copy of OCA 
information in the manner prescribed by this section.
    (b) Reading-room access. Paper copies of OCA information shall be 
available in at least 50 reading rooms geographically distributed across 
the United States and its territories. The reading rooms shall allow any 
person to read, but not remove or mechanically reproduce, a paper copy 
of OCA information, in accordance with paragraphs (c) through (g) of 
this section and procedures established by the Administrator and 
Attorney General.
    (c) Limited number. Any person shall be provided with access to a 
paper copy of the OCA information for up to 10 stationary sources 
located anywhere in the country, without geographical restriction, in a 
calendar month.
    (d) Additional access. Any person also shall be provided with access 
to a paper

[[Page 639]]

copy of the OCA information for stationary sources located in the 
jurisdiction of the LEPC where the person lives or works and for any 
other stationary source that has a vulnerable zone that extends into 
that LEPC's jurisdiction.
    (e) Personal identification for access to OCA information without 
geographical restriction. Reading rooms established under this section 
shall provide a person with access to a paper copy of OCA information 
under paragraph (c) of this section only after a reading room 
representative has
    (1) Ascertained the person's identity by viewing photo 
identification issued by a Federal, State, or local government agency to 
the person; and
    (2) Obtained the person's signature on a sign-in sheet and a 
certification that the person has not received access to OCA information 
for more than 10 stationary sources for that calendar month.
    (f) Personal identification for access to local OCA information. 
Reading rooms established under this section shall provide a person with 
access to a paper copy of OCA information under paragraph (d) of this 
section only after a reading room representative has
    (1) Ascertained where the person lives or works by viewing 
appropriate documentation; and
    (2) Obtained the person's signature on a sign-in sheet.
    (g) Record keeping. Reading room personnel shall keep records of 
reading room use and certifications in accordance with procedures 
established by the Administrator and the Attorney General. These records 
shall be retained for no more than three years. Federal reading rooms 
will not index or otherwise manipulate the sign-in sheets according to 
individuals' names, except in accordance with the Privacy Act.



Sec.  1400.4  Vulnerable zone indicator system.

    (a) In general. The Administrator shall provide access to a 
computer-based indicator that shall inform any person located in any 
state whether an address specified by that person might be within the 
vulnerable zone of one or more stationary sources, according to the data 
reported in RMPs. The indicator also shall provide information about how 
to obtain further information.
    (b) Methods of access. The indicator shall be available on the 
Internet or by request made by telephone or by mail to the Administrator 
to operate the indicator for an address specified by the requestor. 
SERCs, LEPCs, and other related state or local government agencies are 
authorized and encouraged to operate the indicator as well.



Sec.  1400.5  Internet access to certain off-site consequence analysis data elements.

    The Administrator shall include only the following OCA data elements 
in the risk management plan database available on the Internet:
    (a) The concentration of the chemical (RMP Sections 2.1.b; 3.1.b);
    (b) The physical state of the chemical (RMP Sections 2.2; 3.2);
    (c) The statistical model used (RMP Sections 2.3; 3.3; 4.2; 5.2);
    (d) The endpoint used for flammables in the worst-case scenario (RMP 
Section 4.5);
    (e) The duration of the chemical release for the worst-case scenario 
(RMP Section 2.7);
    (f) The wind speed during the chemical release (RMP Sections 2.8; 
3.8);
    (g) The atmospheric stability (RMP Sections 2.9; 3.9);
    (h) The topography of the surrounding area (RMP Sections 2.10; 
3.10);
    (i) The passive mitigation systems considered (RMP Sections 2.15; 
3.15; 4.10; 5.10); and
    (j) The active mitigation systems considered (RMP Sections 3.16; 
5.11).



Sec.  1400.6  Enhanced local access.

    (a) OCA data elements. Consistent with 42 U.S.C. 
7412(r)(7)(H)(xii)(II), members of LEPCs and SERCs, and any other State 
or local government official, may convey to the public OCA data elements 
orally or in writing, as long as the data elements are not conveyed in 
the format of sections 2 through 5 of an RMP or any electronic database 
developed by the Administrator from those sections. Disseminating OCA 
data elements to the public

[[Page 640]]

in a manner consistent with this provision does not violate 42 U.S.C. 
7412(r)(7)(H)(v) and is not punishable under federal law.
    (b) OCA information. (1) LEPCs and related local government agencies 
are authorized and encouraged to allow any member of the public to read, 
but not remove or mechanically copy, a paper copy of the OCA sections of 
RMPs (i.e., sections 2 through 5) for stationary sources located within 
the jurisdiction of the LEPC and for any other stationary source that 
has a vulnerable zone that extends into that jurisdiction.
    (2) LEPCs and related local government agencies that provide read-
only access to the OCA sections of RMPs under this paragraph (b) are not 
required to limit the number of stationary sources for which a person 
can gain access, ascertain a person's identity or place of residence or 
work, or keep records of public access provided.
    (3) SERCs and related state government agencies are authorized and 
encouraged to allow any person to read, but not remove or mechanically 
copy, a paper copy of the OCA sections of RMPs for the same stationary 
sources that the LEPC in whose jurisdiction the person lives or works 
would be authorized to make available to that person under paragraph 
(b)(1) of this section.
    (4) Any LEPC, SERC, or related local or State government agency that 
allows a person to read the OCA sections of RMPs in a manner consistent 
with this paragraph (b) shall not be in violation of 42 U.S.C. 
7412(r)(7)(H)(v) or any other provision of federal law.



    Subpart C_Access to Off-Site Consequence Analysis Information by 
                          Government Officials.



Sec.  1400.7  In general.

    The Administrator shall provide OCA information to government 
officials as provided in this subpart. Any OCA information provided to 
government officials shall be accompanied by a copy of the notice 
prescribed by 42 U.S.C. 7412(r)(7)(H)(vi).



Sec.  1400.8  Access to off-site consequence analysis information
by Federal government officials.

    The Administrator shall provide any Federal government official with 
the OCA information requested by the official for official use. The 
Administrator shall provide the OCA information to the official in 
electronic form, unless the official specifically requests the 
information in paper form. The Administrator may charge a fee to cover 
the cost of copying OCA information in paper form.



Sec.  1400.9  Access to off-site consequence analysis information
by State and local government officials.

    (a) The Administrator shall make available to any State or local 
government official for official use the OCA information for stationary 
sources located in the official's state.
    (b) The Administrator also shall make available to any State or 
local government official for official use the OCA information for 
stationary sources not located in the official's state, at the request 
of the official.
    (c) The Administrator shall provide OCA information to a State or 
local government official in electronic form, unless the official 
specifically requests the information in paper form. The Administrator 
may charge a fee to cover the cost of copying OCA information in paper 
form.
    (d) Any State or local government official is authorized to provide, 
for official use, OCA information relating to stationary sources located 
in the official's state to other State or local government officials in 
that state and to State or local government officials in a contiguous 
state.



                       Subpart D_Other Provisions



Sec.  1400.10  Limitation on public dissemination.

    Except as authorized by this part and by 42 U.S.C. 
7412(r)(7)(H)(v)(III), Federal, State, and local government officials, 
and qualified researchers are prohibited from disseminating OCA 
information and OCA rankings to the public. Violation of this provision 
subjects the violator to criminal liability as provided in 42 U.S.C. 
7412(r)(7)(H)(v)

[[Page 641]]

and civil liability as provided in 42 U.S.C. 7413.



Sec.  1400.11  Limitation on dissemination to State and local government officials.

    Except as authorized by this part and by 42 U.S.C. 
7412(r)(7)(H)(v)(III), Federal, State, and local government officials, 
and qualified researchers are prohibited from disseminating OCA 
information to State and local government officials. Violation of this 
provision subjects the violator to civil liability as provided in 42 
U.S.C. 7413.



Sec.  1400.12  Qualified researchers.

    The Administrator is authorized to provide OCA information, 
including facility identification, to qualified researchers pursuant to 
a system developed and implemented under 42 U.S.C. 7412(r)(7)(H)(vii), 
in consultation with the Attorney General.



Sec.  1400.13  Read-only database.

    The Administrator is authorized to establish, pursuant to 42 U.S.C. 
7412(r)(7)(H)(viii), an information technology system that makes 
available to the public off-site consequence analysis information by 
means of a central database under the control of the Federal government 
that contains information that users may read, but that provides no 
means by which an electronic or mechanical copy of the information may 
be made.

                       PARTS 1401	1499 [RESERVED]

[[Page 643]]



               CHAPTER V--COUNCIL ON ENVIRONMENTAL QUALITY




  --------------------------------------------------------------------

SUBCHAPTER A--NATIONAL ENVIRONMENTAL POLICY ACT IMPLEMENTING REGULATIONS
Part                                                                Page
1500            Purpose and policy..........................         645
1501            NEPA and agency planning....................         648
1502            Environmental impact statement..............         655
1503            Commenting on Environmental impact 
                    statements..............................         662
1504            Pre-decisional referrals to the Council of 
                    proposed Federal actions determined to 
                    be environmentally unsatisfactory.......         664
1505            NEPA and agency decision making.............         665
1506            Other requirements of NEPA..................         666
1507            Agency compliance...........................         672
1508            Definitions.................................         674
         SUBCHAPTER B--ADMINISTRATIVE PROCEDURES AND OPERATIONS
1515            Freedom of Information Act procedures.......         679
1516            Privacy Act implementation..................         685
1517            Public meeting procedures of the Council on 
                    Environmental Quality...................         687
1518            Office of Environmental Quality Management 
                    Fund....................................         691
1519-1599

 [Reserved]

[[Page 645]]



 SUBCHAPTER A_NATIONAL ENVIRONMENTAL POLICY ACT IMPLEMENTING REGULATIONS





PART 1500_PURPOSE AND POLICY--Table of Contents



Sec.
1500.1 Purpose and policy.
1500.2 [Reserved]
1500.3 NEPA compliance.
1500.4 Reducing paperwork.
1500.5 Reducing delay.
1500.6 Agency authority.

    Authority: 42 U.S.C. 4321-4347; 42 U.S.C. 4371-4375; 42 U.S.C. 7609; 
E.O. 11514, 35 FR 4247, 3 CFR, 1966-1970, Comp., p. 902, as amended by 
E.O. 11991, 42 FR 26967, 3 CFR, 1977 Comp., p. 123; and E.O. 13807, 82 
FR 40463, 3 CFR, 2017, Comp., p. 369.

    Source: 85 FR 43357, July 16, 2020, unless otherwise noted.



Sec.  1500.1  Purpose and policy.

    (a) The National Environmental Policy Act (NEPA) is a procedural 
statute intended to ensure Federal agencies consider the environmental 
impacts of their actions in the decision-making process. Section 101 of 
NEPA establishes the national environmental policy of the Federal 
Government to use all practicable means and measures to foster and 
promote the general welfare, create and maintain conditions under which 
man and nature can exist in productive harmony, and fulfill the social, 
economic, and other requirements of present and future generations of 
Americans. Section 102(2) of NEPA establishes the procedural 
requirements to carry out the policy stated in section 101 of NEPA. In 
particular, it requires Federal agencies to provide a detailed statement 
on proposals for major Federal actions significantly affecting the 
quality of the human environment. The purpose and function of NEPA is 
satisfied if Federal agencies have considered relevant environmental 
information, and the public has been informed regarding the decision-
making process. NEPA does not mandate particular results or substantive 
outcomes. NEPA's purpose is not to generate paperwork or litigation, but 
to provide for informed decision making and foster excellent action.
    (b) The regulations in this subchapter implement section 102(2) of 
NEPA. They provide direction to Federal agencies to determine what 
actions are subject to NEPA's procedural requirements and the level of 
NEPA review where applicable. The regulations in this subchapter are 
intended to ensure that relevant environmental information is identified 
and considered early in the process in order to ensure informed decision 
making by Federal agencies. The regulations in this subchapter are also 
intended to ensure that Federal agencies conduct environmental reviews 
in a coordinated, consistent, predictable and timely manner, and to 
reduce unnecessary burdens and delays. Finally, the regulations in this 
subchapter promote concurrent environmental reviews to ensure timely and 
efficient decision making.



Sec.  1500.2  [Reserved]



Sec.  1500.3  NEPA compliance.

    (a) Mandate. This subchapter is applicable to and binding on all 
Federal agencies for implementing the procedural provisions of the 
National Environmental Policy Act of 1969, as amended (Pub. L. 91-190, 
42 U.S.C. 4321 et seq.) (NEPA or the Act), except where compliance would 
be inconsistent with other statutory requirements. The regulations in 
this subchapter are issued pursuant to NEPA; the Environmental Quality 
Improvement Act of 1970, as amended (Pub. L. 91-224, 42 U.S.C. 4371 et 
seq.); section 309 of the Clean Air Act, as amended (42 U.S.C. 7609); 
Executive Order 11514, Protection and Enhancement of Environmental 
Quality (March 5, 1970), as amended by Executive Order 11991, Relating 
to the Protection and Enhancement of Environmental Quality (May 24, 
1977); and Executive Order 13807, Establishing Discipline and 
Accountability in the Environmental Review and Permitting Process for 
Infrastructure Projects (August 15, 2017). The regulations in this 
subchapter apply to the whole of section 102(2) of NEPA. The provisions 
of the Act and the regulations in this subchapter must be read

[[Page 646]]

together as a whole to comply with the law.
    (b) Exhaustion. (1) To ensure informed decision making and reduce 
delays, agencies shall include a request for comments on potential 
alternatives and impacts, and identification of any relevant 
information, studies, or analyses of any kind concerning impacts 
affecting the quality of the human environment in the notice of intent 
to prepare an environmental impact statement (Sec.  1501.9(d)(7) of this 
chapter).
    (2) The draft and final environmental impact statements shall 
include a summary of all alternatives, information, and analyses 
submitted by State, Tribal, and local governments and other public 
commenters for consideration by the lead and cooperating agencies in 
developing the draft and final environmental impact statements (Sec.  
1502.17 of this chapter).
    (3) For consideration by the lead and cooperating agencies, State, 
Tribal, and local governments and other public commenters must submit 
comments within the comment periods provided, and comments shall be as 
specific as possible (Sec. Sec.  1503.1 and 1503.3 of this chapter). 
Comments or objections of any kind not submitted, including those based 
on submitted alternatives, information, and analyses, shall be forfeited 
as unexhausted.
    (4) Informed by the submitted alternatives, information, and 
analyses, including the summary in the final environmental impact 
statement (Sec.  1502.17 of this chapter) and the agency's response to 
comments in the final environmental impact statement (Sec.  1503.4 of 
this chapter), together with any other material in the record that he or 
she determines relevant, the decision maker shall certify in the record 
of decision that the agency considered all of the alternatives, 
information, and analyses, and objections submitted by States, Tribal, 
and local governments and other public commenters for consideration by 
the lead and cooperating agencies in developing the environmental impact 
statement (Sec.  1505.2(b) of this chapter).
    (c) Review of NEPA compliance. It is the Council's intention that 
judicial review of agency compliance with the regulations in this 
subchapter not occur before an agency has issued the record of decision 
or taken other final agency action. It is the Council's intention that 
any allegation of noncompliance with NEPA and the regulations in this 
subchapter should be resolved as expeditiously as possible. Consistent 
with their organic statutes, and as part of implementing the exhaustion 
provisions in paragraph (b) of this section, agencies may structure 
their procedures to include an appropriate bond or other security 
requirement.
    (d) Remedies. Harm from the failure to comply with NEPA can be 
remedied by compliance with NEPA's procedural requirements as 
interpreted in the regulations in this subchapter. It is the Council's 
intention that the regulations in this subchapter create no presumption 
that violation of NEPA is a basis for injunctive relief or for a finding 
of irreparable harm. The regulations in this subchapter do not create a 
cause of action or right of action for violation of NEPA, which contains 
no such cause of action or right of action. It is the Council's 
intention that any actions to review, enjoin, stay, vacate, or otherwise 
alter an agency decision on the basis of an alleged NEPA violation be 
raised as soon as practicable after final agency action to avoid or 
minimize any costs to agencies, applicants, or any affected third 
parties. It is also the Council's intention that minor, non-substantive 
errors that have no effect on agency decision making shall be considered 
harmless and shall not invalidate an agency action.
    (e) Severability. The sections of this subchapter are separate and 
severable from one another. If any section or portion therein is stayed 
or determined to be invalid, or the applicability of any section to any 
person or entity is held invalid, it is the Council's intention that the 
validity of the remainder of those parts shall not be affected, with the 
remaining sections to continue in effect.



Sec.  1500.4  Reducing paperwork.

    Agencies shall reduce excessive paperwork by:
    (a) Using categorical exclusions to define categories of actions 
that normally do not have a significant effect

[[Page 647]]

on the human environment and therefore do not require preparation of an 
environmental impact statement (Sec.  1501.4 of this chapter).
    (b) Using a finding of no significant impact when an action not 
otherwise excluded will not have a significant effect on the human 
environment and therefore does not require preparation of an 
environmental impact statement (Sec.  1501.6 of this chapter).
    (c) Reducing the length of environmental documents by means such as 
meeting appropriate page limits (Sec. Sec.  1501.5(f) and 1502.7 of this 
chapter).
    (d) Preparing analytic and concise environmental impact statements 
(Sec.  1502.2 of this chapter).
    (e) Discussing only briefly issues other than significant ones 
(Sec.  1502.2(b) of this chapter).
    (f) Writing environmental impact statements in plain language (Sec.  
1502.8 of this chapter).
    (g) Following a clear format for environmental impact statements 
(Sec.  1502.10 of this chapter).
    (h) Emphasizing the portions of the environmental impact statement 
that are useful to decision makers and the public (e.g., Sec. Sec.  
1502.14 and 1502.15 of this chapter) and reducing emphasis on background 
material (Sec.  1502.1 of this chapter).
    (i) Using the scoping process, not only to identify significant 
environmental issues deserving of study, but also to deemphasize 
insignificant issues, narrowing the scope of the environmental impact 
statement process accordingly (Sec.  1501.9 of this chapter).
    (j) Summarizing the environmental impact statement (Sec.  1502.12 of 
this chapter).
    (k) Using programmatic, policy, or plan environmental impact 
statements and tiering from statements of broad scope to those of 
narrower scope, to eliminate repetitive discussions of the same issues 
(Sec. Sec.  1501.11 and 1502.4 of this chapter).
    (l) Incorporating by reference (Sec.  1501.12 of this chapter).
    (m) Integrating NEPA requirements with other environmental review 
and consultation requirements (Sec.  1502.24 of this chapter).
    (n) Requiring comments to be as specific as possible (Sec.  1503.3 
of this chapter).
    (o) Attaching and publishing only changes to the draft environmental 
impact statement, rather than rewriting and publishing the entire 
statement when changes are minor (Sec.  1503.4(c) of this chapter).
    (p) Eliminating duplication with State, Tribal, and local 
procedures, by providing for joint preparation of environmental 
documents where practicable (Sec.  1506.2 of this chapter), and with 
other Federal procedures, by providing that an agency may adopt 
appropriate environmental documents prepared by another agency (Sec.  
1506.3 of this chapter).
    (q) Combining environmental documents with other documents (Sec.  
1506.4 of this chapter).



Sec.  1500.5  Reducing delay.

    Agencies shall reduce delay by:
    (a) Using categorical exclusions to define categories of actions 
that normally do not have a significant effect on the human environment 
(Sec.  1501.4 of this chapter) and therefore do not require preparation 
of an environmental impact statement.
    (b) Using a finding of no significant impact when an action not 
otherwise excluded will not have a significant effect on the human 
environment (Sec.  1501.6 of this chapter) and therefore does not 
require preparation of an environmental impact statement.
    (c) Integrating the NEPA process into early planning (Sec.  1501.2 
of this chapter).
    (d) Engaging in interagency cooperation before or as the 
environmental assessment or environmental impact statement is prepared, 
rather than awaiting submission of comments on a completed document 
(Sec. Sec.  1501.7 and 1501.8 of this chapter).
    (e) Ensuring the swift and fair resolution of lead agency disputes 
(Sec.  1501.7 of this chapter).
    (f) Using the scoping process for an early identification of what 
are and what are not the real issues (Sec.  1501.9 of this chapter).
    (g) Meeting appropriate time limits for the environmental assessment 
and

[[Page 648]]

environmental impact statement processes (Sec.  1501.10 of this 
chapter).
    (h) Preparing environmental impact statements early in the process 
(Sec.  1502.5 of this chapter).
    (i) Integrating NEPA requirements with other environmental review 
and consultation requirements (Sec.  1502.24 of this chapter).
    (j) Eliminating duplication with State, Tribal, and local procedures 
by providing for joint preparation of environmental documents where 
practicable (Sec.  1506.2 of this chapter) and with other Federal 
procedures by providing that agencies may jointly prepare or adopt 
appropriate environmental documents prepared by another agency (Sec.  
1506.3 of this chapter).
    (k) Combining environmental documents with other documents (Sec.  
1506.4 of this chapter).
    (l) Using accelerated procedures for proposals for legislation 
(Sec.  1506.8 of this chapter).



Sec.  1500.6  Agency authority.

    Each agency shall interpret the provisions of the Act as a 
supplement to its existing authority and as a mandate to view policies 
and missions in the light of the Act's national environmental 
objectives, to the extent consistent with its existing authority. 
Agencies shall review their policies, procedures, and regulations 
accordingly and revise them as necessary to ensure full compliance with 
the purposes and provisions of the Act as interpreted by the regulations 
in this subchapter. The phrase ``to the fullest extent possible'' in 
section 102 of NEPA means that each agency of the Federal Government 
shall comply with that section, consistent with Sec.  1501.1 of this 
chapter. Nothing contained in the regulations in this subchapter is 
intended or should be construed to limit an agency's other authorities 
or legal responsibilities.



PART 1501_NEPA AND AGENCY PLANNING--Table of Contents



Sec.
1501.1 NEPA thresholds.
1501.2 Apply NEPA early in the process.
1501.3 Determine the appropriate level of NEPA review.
1501.4 Categorical exclusions.
1501.5 Environmental assessments.
1501.6 Findings of no significant impact.
1501.7 Lead agencies.
1501.8 Cooperating agencies.
1501.9 Scoping.
1501.10 Time limits.
1501.11 Tiering.
1501.12 Incorporation by reference.

    Authority: 42 U.S.C. 4321-4347; 42 U.S.C. 4371-4375; 42 U.S.C. 7609; 
E.O. 11514, 35 FR 4247, 35 FR 4247, 3 CFR, 1966-1970, Comp., p. 902, as 
amended by E.O. 11991, 42 FR 26967, 3 CFR, 1977 Comp., p. 123; and E.O. 
13807, 82 FR 40463, 3 CFR, 2017, Comp., p. 369.

    Source: 85 FR 43359, July 16, 2020, unless otherwise noted.



Sec.  1501.1  NEPA thresholds.

    (a) In assessing whether NEPA applies or is otherwise fulfilled, 
Federal agencies should determine:
    (1) Whether the proposed activity or decision is expressly exempt 
from NEPA under another statute;
    (2) Whether compliance with NEPA would clearly and fundamentally 
conflict with the requirements of another statute;
    (3) Whether compliance with NEPA would be inconsistent with 
Congressional intent expressed in another statute;
    (4) Whether the proposed activity or decision is a major Federal 
action;
    (5) Whether the proposed activity or decision, in whole or in part, 
is a non-discretionary action for which the agency lacks authority to 
consider environmental effects as part of its decision-making process; 
and
    (6) Whether the proposed action is an action for which another 
statute's requirements serve the function of agency compliance with the 
Act.
    (b) Federal agencies may make determinations under this section in 
their agency NEPA procedures (Sec.  1507.3(d) of this chapter) or on an 
individual basis, as appropriate.
    (1) Federal agencies may seek the Council's assistance in making an 
individual determination under this section.
    (2) An agency shall consult with other Federal agencies concerning 
their concurrence in statutory determinations made under this section 
where more than one Federal agency administers the statute.

[[Page 649]]



Sec.  1501.2  Apply NEPA early in the process.

    (a) Agencies should integrate the NEPA process with other planning 
and authorization processes at the earliest reasonable time to ensure 
that agencies consider environmental impacts in their planning and 
decisions, to avoid delays later in the process, and to head off 
potential conflicts.
    (b) Each agency shall:
    (1) Comply with the mandate of section 102(2)(A) of NEPA to utilize 
a systematic, interdisciplinary approach which will ensure the 
integrated use of the natural and social sciences and the environmental 
design arts in planning and in decision making which may have an impact 
on man's environment, as specified by Sec.  1507.2(a) of this chapter.
    (2) Identify environmental effects and values in adequate detail so 
the decision maker can appropriately consider such effects and values 
alongside economic and technical analyses. Whenever practicable, 
agencies shall review and publish environmental documents and 
appropriate analyses at the same time as other planning documents.
    (3) Study, develop, and describe appropriate alternatives to 
recommended courses of action in any proposal that involves unresolved 
conflicts concerning alternative uses of available resources as provided 
by section 102(2)(E) of NEPA.
    (4) Provide for actions subject to NEPA that are planned by private 
applicants or other non-Federal entities before Federal involvement so 
that:
    (i) Policies or designated staff are available to advise potential 
applicants of studies or other information foreseeably required for 
later Federal action.
    (ii) The Federal agency consults early with appropriate State, 
Tribal, and local governments and with interested private persons and 
organizations when their involvement is reasonably foreseeable.
    (iii) The Federal agency commences its NEPA process at the earliest 
reasonable time (Sec. Sec.  1501.5(d) and 1502.5(b) of this chapter).



Sec.  1501.3  Determine the appropriate level of NEPA review.

    (a) In assessing the appropriate level of NEPA review, Federal 
agencies should determine whether the proposed action:
    (1) Normally does not have significant effects and is categorically 
excluded (Sec.  1501.4);
    (2) Is not likely to have significant effects or the significance of 
the effects is unknown and is therefore appropriate for an environmental 
assessment (Sec.  1501.5); or
    (3) Is likely to have significant effects and is therefore 
appropriate for an environmental impact statement (part 1502 of this 
chapter).
    (b) In considering whether the effects of the proposed action are 
significant, agencies shall analyze the potentially affected environment 
and degree of the effects of the action. Agencies should consider 
connected actions consistent with Sec.  1501.9(e)(1).
    (1) In considering the potentially affected environment, agencies 
should consider, as appropriate to the specific action, the affected 
area (national, regional, or local) and its resources, such as listed 
species and designated critical habitat under the Endangered Species 
Act. Significance varies with the setting of the proposed action. For 
instance, in the case of a site-specific action, significance would 
usually depend only upon the effects in the local area.
    (2) In considering the degree of the effects, agencies should 
consider the following, as appropriate to the specific action:
    (i) Both short- and long-term effects.
    (ii) Both beneficial and adverse effects.
    (iii) Effects on public health and safety.
    (iv) Effects that would violate Federal, State, Tribal, or local law 
protecting the environment.



Sec.  1501.4  Categorical exclusions.

    (a) For efficiency, agencies shall identify in their agency NEPA 
procedures (Sec.  1507.3(e)(2)(ii) of this chapter) categories of 
actions that normally do not have a significant effect on the human 
environment, and therefore do

[[Page 650]]

not require preparation of an environmental assessment or environmental 
impact statement.
    (b) If an agency determines that a categorical exclusion identified 
in its agency NEPA procedures covers a proposed action, the agency shall 
evaluate the action for extraordinary circumstances in which a normally 
excluded action may have a significant effect.
    (1) If an extraordinary circumstance is present, the agency 
nevertheless may categorically exclude the proposed action if the agency 
determines that there are circumstances that lessen the impacts or other 
conditions sufficient to avoid significant effects.
    (2) If the agency cannot categorically exclude the proposed action, 
the agency shall prepare an environmental assessment or environmental 
impact statement, as appropriate.



Sec.  1501.5  Environmental assessments.

    (a) An agency shall prepare an environmental assessment for a 
proposed action that is not likely to have significant effects or when 
the significance of the effects is unknown unless the agency finds that 
a categorical exclusion (Sec.  1501.4) is applicable or has decided to 
prepare an environmental impact statement.
    (b) An agency may prepare an environmental assessment on any action 
in order to assist agency planning and decision making.
    (c) An environmental assessment shall:
    (1) Briefly provide sufficient evidence and analysis for determining 
whether to prepare an environmental impact statement or a finding of no 
significant impact; and
    (2) Briefly discuss the purpose and need for the proposed action, 
alternatives as required by section 102(2)(E) of NEPA, and the 
environmental impacts of the proposed action and alternatives, and 
include a listing of agencies and persons consulted.
    (d) For applications to the agency requiring an environmental 
assessment, the agency shall commence the environmental assessment as 
soon as practicable after receiving the application.
    (e) Agencies shall involve the public, State, Tribal, and local 
governments, relevant agencies, and any applicants, to the extent 
practicable in preparing environmental assessments.
    (f) The text of an environmental assessment shall be no more than 75 
pages, not including appendices, unless a senior agency official 
approves in writing an assessment to exceed 75 pages and establishes a 
new page limit.
    (g) Agencies may apply the following provisions to environmental 
assessments:
    (1) Section 1502.21 of this chapter--Incomplete or unavailable 
information;
    (2) Section 1502.23 of this chapter--Methodology and scientific 
accuracy; and
    (3) Section 1502.24 of this chapter--Environmental review and 
consultation requirements.



Sec.  1501.6  Findings of no significant impact.

    (a) An agency shall prepare a finding of no significant impact if 
the agency determines, based on the environmental assessment, not to 
prepare an environmental impact statement because the proposed action 
will not have significant effects.
    (1) The agency shall make the finding of no significant impact 
available to the affected public as specified in Sec.  1506.6(b) of this 
chapter.
    (2) In the following circumstances, the agency shall make the 
finding of no significant impact available for public review for 30 days 
before the agency makes its final determination whether to prepare an 
environmental impact statement and before the action may begin:
    (i) The proposed action is or is closely similar to one that 
normally requires the preparation of an environmental impact statement 
under the procedures adopted by the agency pursuant to Sec.  1507.3 of 
this chapter; or
    (ii) The nature of the proposed action is one without precedent.
    (b) The finding of no significant impact shall include the 
environmental assessment or incorporate it by reference and shall note 
any other environmental documents related to it (Sec.  1501.9(f)(3)). If 
the assessment is included, the finding need not repeat any of the 
discussion in the assessment but may incorporate it by reference.

[[Page 651]]

    (c) The finding of no significant impact shall state the authority 
for any mitigation that the agency has adopted and any applicable 
monitoring or enforcement provisions. If the agency finds no significant 
impacts based on mitigation, the mitigated finding of no significant 
impact shall state any enforceable mitigation requirements or 
commitments that will be undertaken to avoid significant impacts.



Sec.  1501.7  Lead agencies.

    (a) A lead agency shall supervise the preparation of an 
environmental impact statement or a complex environmental assessment if 
more than one Federal agency either:
    (1) Proposes or is involved in the same action; or
    (2) Is involved in a group of actions directly related to each other 
because of their functional interdependence or geographical proximity.
    (b) Federal, State, Tribal, or local agencies, including at least 
one Federal agency, may act as joint lead agencies to prepare an 
environmental impact statement or environmental assessment (Sec.  1506.2 
of this chapter).
    (c) If an action falls within the provisions of paragraph (a) of 
this section, the potential lead agencies shall determine, by letter or 
memorandum, which agency will be the lead agency and which will be 
cooperating agencies. The agencies shall resolve the lead agency 
question so as not to cause delay. If there is disagreement among the 
agencies, the following factors (which are listed in order of descending 
importance) shall determine lead agency designation:
    (1) Magnitude of agency's involvement.
    (2) Project approval or disapproval authority.
    (3) Expertise concerning the action's environmental effects.
    (4) Duration of agency's involvement.
    (5) Sequence of agency's involvement.
    (d) Any Federal agency, or any State, Tribal, or local agency or 
private person substantially affected by the absence of lead agency 
designation, may make a written request to the senior agency officials 
of the potential lead agencies that a lead agency be designated.
    (e) If Federal agencies are unable to agree on which agency will be 
the lead agency or if the procedure described in paragraph (c) of this 
section has not resulted in a lead agency designation within 45 days, 
any of the agencies or persons concerned may file a request with the 
Council asking it to determine which Federal agency shall be the lead 
agency. A copy of the request shall be transmitted to each potential 
lead agency. The request shall consist of:
    (1) A precise description of the nature and extent of the proposed 
action; and
    (2) A detailed statement of why each potential lead agency should or 
should not be the lead agency under the criteria specified in paragraph 
(c) of this section.
    (f) Any potential lead agency may file a response within 20 days 
after a request is filed with the Council. As soon as possible, but not 
later than 20 days after receiving the request and all responses to it, 
the Council shall determine which Federal agency will be the lead agency 
and which other Federal agencies will be cooperating agencies.
    (g) To the extent practicable, if a proposal will require action by 
more than one Federal agency and the lead agency determines that it 
requires preparation of an environmental impact statement, the lead and 
cooperating agencies shall evaluate the proposal in a single 
environmental impact statement and issue a joint record of decision. To 
the extent practicable, if a proposal will require action by more than 
one Federal agency and the lead agency determines that it requires 
preparation of an environmental assessment, the lead and cooperating 
agencies should evaluate the proposal in a single environmental 
assessment and, where appropriate, issue a joint finding of no 
significant impact.
    (h) With respect to cooperating agencies, the lead agency shall:
    (1) Request the participation of each cooperating agency in the NEPA 
process at the earliest practicable time.
    (2) Use the environmental analysis and proposals of cooperating 
agencies

[[Page 652]]

with jurisdiction by law or special expertise, to the maximum extent 
practicable.
    (3) Meet with a cooperating agency at the latter's request.
    (4) Determine the purpose and need, and alternatives in consultation 
with any cooperating agency.
    (i) The lead agency shall develop a schedule, setting milestones for 
all environmental reviews and authorizations required for implementation 
of the action, in consultation with any applicant and all joint lead, 
cooperating, and participating agencies, as soon as practicable.
    (j) If the lead agency anticipates that a milestone will be missed, 
it shall notify appropriate officials at the responsible agencies. As 
soon as practicable, the responsible agencies shall elevate the issue to 
the appropriate officials of the responsible agencies for timely 
resolution.



Sec.  1501.8  Cooperating agencies.

    (a) The purpose of this section is to emphasize agency cooperation 
early in the NEPA process. Upon request of the lead agency, any Federal 
agency with jurisdiction by law shall be a cooperating agency. In 
addition, upon request of the lead agency, any other Federal agency with 
special expertise with respect to any environmental issue may be a 
cooperating agency. A State, Tribal, or local agency of similar 
qualifications may become a cooperating agency by agreement with the 
lead agency. An agency may request that the lead agency designate it a 
cooperating agency, and a Federal agency may appeal a denial of its 
request to the Council, in accordance with Sec.  1501.7(e).
    (b) Each cooperating agency shall:
    (1) Participate in the NEPA process at the earliest practicable 
time.
    (2) Participate in the scoping process (described in Sec.  1501.9).
    (3) On request of the lead agency, assume responsibility for 
developing information and preparing environmental analyses, including 
portions of the environmental impact statement or environmental 
assessment concerning which the cooperating agency has special 
expertise.
    (4) On request of the lead agency, make available staff support to 
enhance the lead agency's interdisciplinary capability.
    (5) Normally use its own funds. To the extent available funds 
permit, the lead agency shall fund those major activities or analyses it 
requests from cooperating agencies. Potential lead agencies shall 
include such funding requirements in their budget requests.
    (6) Consult with the lead agency in developing the schedule (Sec.  
1501.7(i)), meet the schedule, and elevate, as soon as practicable, to 
the senior agency official of the lead agency any issues relating to 
purpose and need, alternatives, or other issues that may affect any 
agencies' ability to meet the schedule.
    (7) Meet the lead agency's schedule for providing comments and limit 
its comments to those matters for which it has jurisdiction by law or 
special expertise with respect to any environmental issue consistent 
with Sec.  1503.2 of this chapter.
    (8) To the maximum extent practicable, jointly issue environmental 
documents with the lead agency.
    (c) In response to a lead agency's request for assistance in 
preparing the environmental documents (described in paragraph (b)(3), 
(4), or (5) of this section), a cooperating agency may reply that other 
program commitments preclude any involvement or the degree of 
involvement requested in the action that is the subject of the 
environmental impact statement or environmental assessment. The 
cooperating agency shall submit a copy of this reply to the Council and 
the senior agency official of the lead agency.



Sec.  1501.9  Scoping.

    (a) Generally. Agencies shall use an early and open process to 
determine the scope of issues for analysis in an environmental impact 
statement, including identifying the significant issues and eliminating 
from further study non-significant issues. Scoping may begin as soon as 
practicable after the proposal for action is sufficiently developed for 
agency consideration. Scoping may include appropriate pre-application 
procedures or work conducted prior to publication of the notice of 
intent.

[[Page 653]]

    (b) Invite cooperating and participating agencies. As part of the 
scoping process, the lead agency shall invite the participation of 
likely affected Federal, State, Tribal, and local agencies and 
governments, the proponent of the action, and other likely affected or 
interested persons (including those who might not be in accord with the 
action), unless there is a limited exception under Sec.  1507.3(f)(1) of 
this chapter.
    (c) Scoping outreach. As part of the scoping process the lead agency 
may hold a scoping meeting or meetings, publish scoping information, or 
use other means to communicate with those persons or agencies who may be 
interested or affected, which the agency may integrate with any other 
early planning meeting. Such a scoping meeting will often be appropriate 
when the impacts of a particular action are confined to specific sites.
    (d) Notice of intent. As soon as practicable after determining that 
a proposal is sufficiently developed to allow for meaningful public 
comment and requires an environmental impact statement, the lead agency 
shall publish a notice of intent to prepare an environmental impact 
statement in the Federal Register, except as provided in Sec.  
1507.3(f)(3) of this chapter. An agency also may publish notice in 
accordance with Sec.  1506.6 of this chapter. The notice shall include, 
as appropriate:
    (1) The purpose and need for the proposed action;
    (2) A preliminary description of the proposed action and 
alternatives the environmental impact statement will consider;
    (3) A brief summary of expected impacts;
    (4) Anticipated permits and other authorizations;
    (5) A schedule for the decision-making process;
    (6) A description of the public scoping process, including any 
scoping meeting(s);
    (7) A request for identification of potential alternatives, 
information, and analyses relevant to the proposed action (see Sec.  
1502.17 of this chapter); and
    (8) Contact information for a person within the agency who can 
answer questions about the proposed action and the environmental impact 
statement.
    (e) Determination of scope. As part of the scoping process, the lead 
agency shall determine the scope and the significant issues to be 
analyzed in depth in the environmental impact statement. To determine 
the scope of environmental impact statements, agencies shall consider:
    (1) Actions (other than unconnected single actions) that may be 
connected actions, which means that they are closely related and 
therefore should be discussed in the same impact statement. Actions are 
connected if they:
    (i) Automatically trigger other actions that may require 
environmental impact statements;
    (ii) Cannot or will not proceed unless other actions are taken 
previously or simultaneously; or
    (iii) Are interdependent parts of a larger action and depend on the 
larger action for their justification.
    (2) Alternatives, which include the no action alternative; other 
reasonable courses of action; and mitigation measures (not in the 
proposed action).
    (3) Impacts.
    (f) Additional scoping responsibilities. As part of the scoping 
process, the lead agency shall:
    (1) Identify and eliminate from detailed study the issues that are 
not significant or have been covered by prior environmental review(s) 
(Sec.  1506.3 of this chapter), narrowing the discussion of these issues 
in the statement to a brief presentation of why they will not have a 
significant effect on the human environment or providing a reference to 
their coverage elsewhere.
    (2) Allocate assignments for preparation of the environmental impact 
statement among the lead and cooperating agencies, with the lead agency 
retaining responsibility for the statement.
    (3) Indicate any public environmental assessments and other 
environmental impact statements that are being or will be prepared and 
are related to but are not part of the scope of the impact statement 
under consideration.
    (4) Identify other environmental review, authorization, and 
consultation

[[Page 654]]

requirements so the lead and cooperating agencies may prepare other 
required analyses and studies concurrently and integrated with the 
environmental impact statement, as provided in Sec.  1502.24 of this 
chapter.
    (5) Indicate the relationship between the timing of the preparation 
of environmental analyses and the agencies' tentative planning and 
decision-making schedule.
    (g) Revisions. An agency shall revise the determinations made under 
paragraphs (b), (c), (e), and (f) of this section if substantial changes 
are made later in the proposed action, or if significant new 
circumstances or information arise which bear on the proposal or its 
impacts.



Sec.  1501.10  Time limits.

    (a) To ensure that agencies conduct NEPA reviews as efficiently and 
expeditiously as practicable, Federal agencies should set time limits 
appropriate to individual actions or types of actions (consistent with 
the time intervals required by Sec.  1506.11 of this chapter).
    (b) To ensure timely decision making, agencies shall complete:
    (1) Environmental assessments within 1 year unless a senior agency 
official of the lead agency approves a longer period in writing and 
establishes a new time limit. One year is measured from the date of 
agency decision to prepare an environmental assessment to the 
publication of an environmental assessment or a finding of no 
significant impact.
    (2) Environmental impact statements within 2 years unless a senior 
agency official of the lead agency approves a longer period in writing 
and establishes a new time limit. Two years is measured from the date of 
the issuance of the notice of intent to the date a record of decision is 
signed.
    (c) The senior agency official may consider the following factors in 
determining time limits:
    (1) Potential for environmental harm.
    (2) Size of the proposed action.
    (3) State of the art of analytic techniques.
    (4) Degree of public need for the proposed action, including the 
consequences of delay.
    (5) Number of persons and agencies affected.
    (6) Availability of relevant information.
    (7) Other time limits imposed on the agency by law, regulations, or 
Executive order.
    (d) The senior agency official may set overall time limits or limits 
for each constituent part of the NEPA process, which may include:
    (1) Decision on whether to prepare an environmental impact statement 
(if not already decided).
    (2) Determination of the scope of the environmental impact 
statement.
    (3) Preparation of the draft environmental impact statement.
    (4) Review of any comments on the draft environmental impact 
statement from the public and agencies.
    (5) Preparation of the final environmental impact statement.
    (6) Review of any comments on the final environmental impact 
statement.
    (7) Decision on the action based in part on the environmental impact 
statement.
    (e) The agency may designate a person (such as the project manager 
or a person in the agency's office with NEPA responsibilities) to 
expedite the NEPA process.
    (f) State, Tribal, or local agencies or members of the public may 
request a Federal agency to set time limits.



Sec.  1501.11  Tiering.

    (a) Agencies should tier their environmental impact statements and 
environmental assessments when it would eliminate repetitive discussions 
of the same issues, focus on the actual issues ripe for decision, and 
exclude from consideration issues already decided or not yet ripe at 
each level of environmental review. Tiering may also be appropriate for 
different stages of actions.
    (b) When an agency has prepared an environmental impact statement or 
environmental assessment for a program or policy and then prepares a 
subsequent statement or assessment on an action included within the 
entire program or policy (such as a project- or

[[Page 655]]

site-specific action), the tiered document needs only to summarize and 
incorporate by reference the issues discussed in the broader document. 
The tiered document shall concentrate on the issues specific to the 
subsequent action. The tiered document shall state where the earlier 
document is available.
    (c) Tiering is appropriate when the sequence from an environmental 
impact statement or environmental assessment is:
    (1) From a programmatic, plan, or policy environmental impact 
statement or environmental assessment to a program, plan, or policy 
statement or assessment of lesser or narrower scope or to a site-
specific statement or assessment.
    (2) From an environmental impact statement or environmental 
assessment on a specific action at an early stage (such as need and site 
selection) to a supplement (which is preferred) or a subsequent 
statement or assessment at a later stage (such as environmental 
mitigation). Tiering in such cases is appropriate when it helps the lead 
agency to focus on the issues that are ripe for decision and exclude 
from consideration issues already decided or not yet ripe.



Sec.  1501.12  Incorporation by reference.

    Agencies shall incorporate material, such as planning studies, 
analyses, or other relevant information, into environmental documents by 
reference when the effect will be to cut down on bulk without impeding 
agency and public review of the action. Agencies shall cite the 
incorporated material in the document and briefly describe its content. 
Agencies may not incorporate material by reference unless it is 
reasonably available for inspection by potentially interested persons 
within the time allowed for comment. Agencies shall not incorporate by 
reference material based on proprietary data that is not available for 
review and comment.



PART 1502_ENVIRONMENTAL IMPACT STATEMENT--Table of Contents



Sec.
1502.1 Purpose of environmental impact statement.
1502.2 Implementation.
1502.3 Statutory requirements for statements.
1502.4 Major Federal actions requiring the preparation of environmental 
          impact statements.
1502.5 Timing.
1502.6 Interdisciplinary preparation.
1502.7 Page limits.
1502.8 Writing.
1502.9 Draft, final, and supplemental statements.
1502.10 Recommended format.
1502.11 Cover.
1502.12 Summary.
1502.13 Purpose and need.
1502.14 Alternatives including the proposed action.
1502.15 Affected environment.
1502.16 Environmental consequences.
1502.17 Summary of submitted alternatives, information, and analyses.
1502.18 List of preparers.
1502.19 Appendix.
1502.20 Publication of the environmental impact statement.
1502.21 Incomplete or unavailable information.
1502.22 Cost-benefit analysis.
1502.23 Methodology and scientific accuracy.
1502.24 Environmental review and consultation requirements.

    Authority: 42 U.S.C. 4321-4347; 42 U.S.C. 4371-4375; 42 U.S.C. 7609; 
and E.O. 11514, 35 FR 4247, 3 CFR, 1966-1970, Comp., p. 902, as amended 
by E.O. 11991, 42 FR 26967, 3 CFR, 1977 Comp., p. 123.

    Source: 85 FR 43363, July 16, 2020, unless otherwise noted.



Sec.  1502.1  Purpose of environmental impact statement.

    The primary purpose of an environmental impact statement prepared 
pursuant to section 102(2)(C) of NEPA is to ensure agencies consider the 
environmental impacts of their actions in decision making. It shall 
provide full and fair discussion of significant environmental impacts 
and shall inform decision makers and the public of reasonable 
alternatives that would avoid or minimize adverse impacts or enhance the 
quality of the human environment. Agencies shall focus on significant 
environmental issues and alternatives and shall reduce paperwork and the 
accumulation of extraneous background data. Statements shall be concise, 
clear, and to the point, and shall be supported by evidence that the 
agency has made the necessary environmental

[[Page 656]]

analyses. An environmental impact statement is a document that informs 
Federal agency decision making and the public.



Sec.  1502.2  Implementation.

    (a) Environmental impact statements shall not be encyclopedic.
    (b) Environmental impact statements shall discuss impacts in 
proportion to their significance. There shall be only brief discussion 
of other than significant issues. As in a finding of no significant 
impact, there should be only enough discussion to show why more study is 
not warranted.
    (c) Environmental impact statements shall be analytic, concise, and 
no longer than necessary to comply with NEPA and with the regulations in 
this subchapter. Length should be proportional to potential 
environmental effects and project size.
    (d) Environmental impact statements shall state how alternatives 
considered in it and decisions based on it will or will not achieve the 
requirements of sections 101 and 102(1) of NEPA as interpreted in the 
regulations in this subchapter and other environmental laws and 
policies.
    (e) The range of alternatives discussed in environmental impact 
statements shall encompass those to be considered by the decision maker.
    (f) Agencies shall not commit resources prejudicing selection of 
alternatives before making a final decision (see also Sec.  1506.1 of 
this chapter).
    (g) Environmental impact statements shall serve as the means of 
assessing the environmental impact of proposed agency actions, rather 
than justifying decisions already made.



Sec.  1502.3  Statutory requirements for statements.

    As required by section 102(2)(C) of NEPA, environmental impact 
statements are to be included in every Federal agency recommendation or 
report on proposals for legislation and other major Federal actions 
significantly affecting the quality of the human environment.



Sec.  1502.4  Major Federal actions requiring the preparation
of environmental impact statements.

    (a) Agencies shall define the proposal that is the subject of an 
environmental impact statement based on the statutory authorities for 
the proposed action. Agencies shall use the criteria for scope (Sec.  
1501.9(e) of this chapter) to determine which proposal(s) shall be the 
subject of a particular statement. Agencies shall evaluate in a single 
environmental impact statement proposals or parts of proposals that are 
related to each other closely enough to be, in effect, a single course 
of action.
    (b) Environmental impact statements may be prepared for programmatic 
Federal actions, such as the adoption of new agency programs. When 
agencies prepare such statements, they should be relevant to the program 
decision and timed to coincide with meaningful points in agency planning 
and decision making.
    (1) When preparing statements on programmatic actions (including 
proposals by more than one agency), agencies may find it useful to 
evaluate the proposal(s) in one of the following ways:
    (i) Geographically, including actions occurring in the same general 
location, such as body of water, region, or metropolitan area.
    (ii) Generically, including actions that have relevant similarities, 
such as common timing, impacts, alternatives, methods of implementation, 
media, or subject matter.
    (iii) By stage of technological development including Federal or 
federally assisted research, development or demonstration programs for 
new technologies that, if applied, could significantly affect the 
quality of the human environment. Statements on such programs should be 
available before the program has reached a stage of investment or 
commitment to implementation likely to determine subsequent development 
or restrict later alternatives.
    (2) Agencies shall as appropriate employ scoping (Sec.  1501.9 of 
this chapter), tiering (Sec.  1501.11 of this chapter), and other 
methods listed in Sec. Sec.  1500.4 and 1500.5 of this chapter to relate 
programmatic and narrow actions and to

[[Page 657]]

avoid duplication and delay. Agencies may tier their environmental 
analyses to defer detailed analysis of environmental impacts of specific 
program elements until such program elements are ripe for final agency 
action.



Sec.  1502.5  Timing.

    An agency should commence preparation of an environmental impact 
statement as close as practicable to the time the agency is developing 
or receives a proposal so that preparation can be completed in time for 
the final statement to be included in any recommendation or report on 
the proposal. The statement shall be prepared early enough so that it 
can serve as an important practical contribution to the decision-making 
process and will not be used to rationalize or justify decisions already 
made (Sec. Sec.  1501.2 of this chapter and 1502.2). For instance:
    (a) For projects directly undertaken by Federal agencies, the agency 
shall prepare the environmental impact statement at the feasibility 
analysis (go/no-go) stage and may supplement it at a later stage, if 
necessary.
    (b) For applications to the agency requiring an environmental impact 
statement, the agency shall commence the statement as soon as 
practicable after receiving the application. Federal agencies should 
work with potential applicants and applicable State, Tribal, and local 
agencies and governments prior to receipt of the application.
    (c) For adjudication, the final environmental impact statement shall 
normally precede the final staff recommendation and that portion of the 
public hearing related to the impact study. In appropriate 
circumstances, the statement may follow preliminary hearings designed to 
gather information for use in the statements.
    (d) For informal rulemaking, the draft environmental impact 
statement shall normally accompany the proposed rule.



Sec.  1502.6  Interdisciplinary preparation.

    Agencies shall prepare environmental impact statements using an 
interdisciplinary approach that will ensure the integrated use of the 
natural and social sciences and the environmental design arts (section 
102(2)(A) of NEPA). The disciplines of the preparers shall be 
appropriate to the scope and issues identified in the scoping process 
(Sec.  1501.9 of this chapter).



Sec.  1502.7  Page limits.

    The text of final environmental impact statements (paragraphs (a)(4) 
through (6) of Sec.  1502.10) shall be 150 pages or fewer and, for 
proposals of unusual scope or complexity, shall be 300 pages or fewer 
unless a senior agency official of the lead agency approves in writing a 
statement to exceed 300 pages and establishes a new page limit.



Sec.  1502.8  Writing.

    Agencies shall write environmental impact statements in plain 
language and may use appropriate graphics so that decision makers and 
the public can readily understand such statements. Agencies should 
employ writers of clear prose or editors to write, review, or edit 
statements, which shall be based upon the analysis and supporting data 
from the natural and social sciences and the environmental design arts.



Sec.  1502.9  Draft, final, and supplemental statements.

    (a) Generally. Except for proposals for legislation as provided in 
Sec.  1506.8 of this chapter, agencies shall prepare environmental 
impact statements in two stages and, where necessary, supplement them, 
as provided in paragraph (d)(1) of this section.
    (b) Draft environmental impact statements. Agencies shall prepare 
draft environmental impact statements in accordance with the scope 
decided upon in the scoping process (Sec.  1501.9 of this chapter). The 
lead agency shall work with the cooperating agencies and shall obtain 
comments as required in part 1503 of this chapter. To the fullest extent 
practicable, the draft statement must meet the requirements established 
for final statements in section 102(2)(C) of NEPA as interpreted in the 
regulations in this subchapter. If a draft statement is so inadequate as 
to preclude meaningful analysis, the agency shall prepare and publish a 
supplemental draft of the appropriate portion. At appropriate points in 
the draft statement, the agency shall discuss all

[[Page 658]]

major points of view on the environmental impacts of the alternatives 
including the proposed action.
    (c) Final environmental impact statements. Final environmental 
impact statements shall address comments as required in part 1503 of 
this chapter. At appropriate points in the final statement, the agency 
shall discuss any responsible opposing view that was not adequately 
discussed in the draft statement and shall indicate the agency's 
response to the issues raised.
    (d) Supplemental environmental impact statements. Agencies:
    (1) Shall prepare supplements to either draft or final environmental 
impact statements if a major Federal action remains to occur, and:
    (i) The agency makes substantial changes to the proposed action that 
are relevant to environmental concerns; or
    (ii) There are significant new circumstances or information relevant 
to environmental concerns and bearing on the proposed action or its 
impacts.
    (2) May also prepare supplements when the agency determines that the 
purposes of the Act will be furthered by doing so.
    (3) Shall prepare, publish, and file a supplement to a statement 
(exclusive of scoping (Sec.  1501.9 of this chapter)) as a draft and 
final statement, as is appropriate to the stage of the statement 
involved, unless the Council approves alternative procedures (Sec.  
1506.12 of this chapter).
    (4) May find that changes to the proposed action or new 
circumstances or information relevant to environmental concerns are not 
significant and therefore do not require a supplement. The agency should 
document the finding consistent with its agency NEPA procedures (Sec.  
1507.3 of this chapter), or, if necessary, in a finding of no 
significant impact supported by an environmental assessment.



Sec.  1502.10  Recommended format.

    (a) Agencies shall use a format for environmental impact statements 
that will encourage good analysis and clear presentation of the 
alternatives including the proposed action. Agencies should use the 
following standard format for environmental impact statements unless the 
agency determines that there is a more effective format for 
communication:
    (1) Cover.
    (2) Summary.
    (3) Table of contents.
    (4) Purpose of and need for action.
    (5) Alternatives including the proposed action (sections 
102(2)(C)(iii) and 102(2)(E) of NEPA).
    (6) Affected environment and environmental consequences (especially 
sections 102(2)(C)(i), (ii), (iv), and (v) of NEPA).
    (7) Submitted alternatives, information, and analyses.
    (8) List of preparers.
    (9) Appendices (if any).
    (b) If an agency uses a different format, it shall include 
paragraphs (a)(1) through (8) of this section, as further described in 
Sec. Sec.  1502.11 through 1502.19, in any appropriate format.



Sec.  1502.11  Cover.

    The cover shall not exceed one page and include:
    (a) A list of the responsible agencies, including the lead agency 
and any cooperating agencies.
    (b) The title of the proposed action that is the subject of the 
statement (and, if appropriate, the titles of related cooperating agency 
actions), together with the State(s) and county(ies) (or other 
jurisdiction(s), if applicable) where the action is located.
    (c) The name, address, and telephone number of the person at the 
agency who can supply further information.
    (d) A designation of the statement as a draft, final, or draft or 
final supplement.
    (e) A one-paragraph abstract of the statement.
    (f) The date by which the agency must receive comments (computed in 
cooperation with EPA under Sec.  1506.11 of this chapter).
    (g) For the final environmental impact statement, the estimated 
total cost to prepare both the draft and final environmental impact 
statement, including the costs of agency full-time equivalent (FTE) 
personnel hours, contractor costs, and other direct costs. If 
practicable and noted where not practicable, agencies also should 
include

[[Page 659]]

costs incurred by cooperating and participating agencies, applicants, 
and contractors.



Sec.  1502.12  Summary.

    Each environmental impact statement shall contain a summary that 
adequately and accurately summarizes the statement. The summary shall 
stress the major conclusions, areas of disputed issues raised by 
agencies and the public, and the issues to be resolved (including the 
choice among alternatives). The summary normally will not exceed 15 
pages.



Sec.  1502.13  Purpose and need.

    The statement shall briefly specify the underlying purpose and need 
to which the agency is responding in proposing the alternatives 
including the proposed action.

[87 FR 23469, Apr. 20, 2022]



Sec.  1502.14  Alternatives including the proposed action.

    The alternatives section should present the environmental impacts of 
the proposed action and the alternatives in comparative form based on 
the information and analysis presented in the sections on the affected 
environment (Sec.  1502.15) and the environmental consequences (Sec.  
1502.16). In this section, agencies shall:
    (a) Evaluate reasonable alternatives to the proposed action, and, 
for alternatives that the agency eliminated from detailed study, briefly 
discuss the reasons for their elimination.
    (b) Discuss each alternative considered in detail, including the 
proposed action, so that reviewers may evaluate their comparative 
merits.
    (c) Include the no action alternative.
    (d) Identify the agency's preferred alternative or alternatives, if 
one or more exists, in the draft statement and identify such alternative 
in the final statement unless another law prohibits the expression of 
such a preference.
    (e) Include appropriate mitigation measures not already included in 
the proposed action or alternatives.
    (f) Limit their consideration to a reasonable number of 
alternatives.



Sec.  1502.15  Affected environment.

    The environmental impact statement shall succinctly describe the 
environment of the area(s) to be affected or created by the alternatives 
under consideration, including the reasonably foreseeable environmental 
trends and planned actions in the area(s). The environmental impact 
statement may combine the description with evaluation of the 
environmental consequences (Sec.  1502.16), and it shall be no longer 
than is necessary to understand the effects of the alternatives. Data 
and analyses in a statement shall be commensurate with the importance of 
the impact, with less important material summarized, consolidated, or 
simply referenced. Agencies shall avoid useless bulk in statements and 
shall concentrate effort and attention on important issues. Verbose 
descriptions of the affected environment are themselves no measure of 
the adequacy of an environmental impact statement.



Sec.  1502.16  Environmental consequences.

    (a) The environmental consequences section forms the scientific and 
analytic basis for the comparisons under Sec.  1502.14. It shall 
consolidate the discussions of those elements required by sections 
102(2)(C)(i), (ii), (iv), and (v) of NEPA that are within the scope of 
the statement and as much of section 102(2)(C)(iii) of NEPA as is 
necessary to support the comparisons. This section should not duplicate 
discussions in Sec.  1502.14. The discussion shall include:
    (1) The environmental impacts of the proposed action and reasonable 
alternatives to the proposed action and the significance of those 
impacts. The comparison of the proposed action and reasonable 
alternatives shall be based on this discussion of the impacts.
    (2) Any adverse environmental effects that cannot be avoided should 
the proposal be implemented.
    (3) The relationship between short-term uses of man's environment 
and the maintenance and enhancement of long-term productivity.
    (4) Any irreversible or irretrievable commitments of resources that 
would be involved in the proposal should it be implemented.
    (5) Possible conflicts between the proposed action and the 
objectives of

[[Page 660]]

Federal, regional, State, Tribal, and local land use plans, policies and 
controls for the area concerned. (Sec.  1506.2(d) of this chapter)
    (6) Energy requirements and conservation potential of various 
alternatives and mitigation measures.
    (7) Natural or depletable resource requirements and conservation 
potential of various alternatives and mitigation measures.
    (8) Urban quality, historic and cultural resources, and the design 
of the built environment, including the reuse and conservation potential 
of various alternatives and mitigation measures.
    (9) Means to mitigate adverse environmental impacts (if not fully 
covered under Sec.  1502.14(e)).
    (10) Where applicable, economic and technical considerations, 
including the economic benefits of the proposed action.
    (b) Economic or social effects by themselves do not require 
preparation of an environmental impact statement. However, when the 
agency determines that economic or social and natural or physical 
environmental effects are interrelated, the environmental impact 
statement shall discuss and give appropriate consideration to these 
effects on the human environment.



Sec.  1502.17  Summary of submitted alternatives, information, and analyses.

    (a) The draft environmental impact statement shall include a summary 
that identifies all alternatives, information, and analyses submitted by 
State, Tribal, and local governments and other public commenters during 
the scoping process for consideration by the lead and cooperating 
agencies in developing the environmental impact statement.
    (1) The agency shall append to the draft environmental impact 
statement or otherwise publish all comments (or summaries thereof where 
the response has been exceptionally voluminous) received during the 
scoping process that identified alternatives, information, and analyses 
for the agency's consideration.
    (2) Consistent with Sec.  1503.1(a)(3) of this chapter, the lead 
agency shall invite comment on the summary identifying all submitted 
alternatives, information, and analyses in the draft environmental 
impact statement.
    (b) The final environmental impact statement shall include a summary 
that identifies all alternatives, information, and analyses submitted by 
State, Tribal, and local governments and other public commenters for 
consideration by the lead and cooperating agencies in developing the 
final environmental impact statement.



Sec.  1502.18  List of preparers.

    The environmental impact statement shall list the names, together 
with their qualifications (expertise, experience, professional 
disciplines), of the persons who were primarily responsible for 
preparing the environmental impact statement or significant background 
papers, including basic components of the statement. Where possible, the 
environmental impact statement shall identify the persons who are 
responsible for a particular analysis, including analyses in background 
papers. Normally the list will not exceed two pages.



Sec.  1502.19  Appendix.

    If an agency prepares an appendix, the agency shall publish it with 
the environmental impact statement, and it shall consist of:
    (a) Material prepared in connection with an environmental impact 
statement (as distinct from material that is not so prepared and is 
incorporated by reference (Sec.  1501.12 of this chapter)).
    (b) Material substantiating any analysis fundamental to the impact 
statement.
    (c) Material relevant to the decision to be made.
    (d) For draft environmental impact statements, all comments (or 
summaries thereof where the response has been exceptionally voluminous) 
received during the scoping process that identified alternatives, 
information, and analyses for the agency's consideration.
    (e) For final environmental impact statements, the comment summaries 
and responses consistent with Sec.  1503.4 of this chapter.

[[Page 661]]



Sec.  1502.20  Publication of the environmental impact statement.

    Agencies shall publish the entire draft and final environmental 
impact statements and unchanged statements as provided in Sec.  
1503.4(c) of this chapter. The agency shall transmit the entire 
statement electronically (or in paper copy, if so requested due to 
economic or other hardship) to:
    (a) Any Federal agency that has jurisdiction by law or special 
expertise with respect to any environmental impact involved and any 
appropriate Federal, State, Tribal, or local agency authorized to 
develop and enforce environmental standards.
    (b) The applicant, if any.
    (c) Any person, organization, or agency requesting the entire 
environmental impact statement.
    (d) In the case of a final environmental impact statement, any 
person, organization, or agency that submitted substantive comments on 
the draft.



Sec.  1502.21  Incomplete or unavailable information.

    (a) When an agency is evaluating reasonably foreseeable significant 
adverse effects on the human environment in an environmental impact 
statement, and there is incomplete or unavailable information, the 
agency shall make clear that such information is lacking.
    (b) If the incomplete but available information relevant to 
reasonably foreseeable significant adverse impacts is essential to a 
reasoned choice among alternatives, and the overall costs of obtaining 
it are not unreasonable, the agency shall include the information in the 
environmental impact statement.
    (c) If the information relevant to reasonably foreseeable 
significant adverse impacts cannot be obtained because the overall costs 
of obtaining it are unreasonable or the means to obtain it are not 
known, the agency shall include within the environmental impact 
statement:
    (1) A statement that such information is incomplete or unavailable;
    (2) A statement of the relevance of the incomplete or unavailable 
information to evaluating reasonably foreseeable significant adverse 
impacts on the human environment;
    (3) A summary of existing credible scientific evidence that is 
relevant to evaluating the reasonably foreseeable significant adverse 
impacts on the human environment; and
    (4) The agency's evaluation of such impacts based upon theoretical 
approaches or research methods generally accepted in the scientific 
community.
    (d) For the purposes of this section, ``reasonably foreseeable'' 
includes impacts that have catastrophic consequences, even if their 
probability of occurrence is low, provided that the analysis of the 
impacts is supported by credible scientific evidence, is not based on 
pure conjecture, and is within the rule of reason.



Sec.  1502.22  Cost-benefit analysis.

    If the agency is considering a cost-benefit analysis for the 
proposed action relevant to the choice among alternatives with different 
environmental effects, the agency shall incorporate the cost-benefit 
analysis by reference or append it to the statement as an aid in 
evaluating the environmental consequences. In such cases, to assess the 
adequacy of compliance with section 102(2)(B) of NEPA (ensuring 
appropriate consideration of unquantified environmental amenities and 
values in decision making, along with economical and technical 
considerations), the statement shall discuss the relationship between 
that analysis and any analyses of unquantified environmental impacts, 
values, and amenities. For purposes of complying with the Act, agencies 
need not display the weighing of the merits and drawbacks of the various 
alternatives in a monetary cost-benefit analysis and should not do so 
when there are important qualitative considerations. However, an 
environmental impact statement should at least indicate those 
considerations, including factors not related to environmental quality, 
that are likely to be relevant and important to a decision.



Sec.  1502.23  Methodology and scientific accuracy.

    Agencies shall ensure the professional integrity, including 
scientific integrity, of the discussions and analyses in environmental 
documents.

[[Page 662]]

Agencies shall make use of reliable existing data and resources. 
Agencies may make use of any reliable data sources, such as remotely 
gathered information or statistical models. They shall identify any 
methodologies used and shall make explicit reference to the scientific 
and other sources relied upon for conclusions in the statement. Agencies 
may place discussion of methodology in an appendix. Agencies are not 
required to undertake new scientific and technical research to inform 
their analyses. Nothing in this section is intended to prohibit agencies 
from compliance with the requirements of other statutes pertaining to 
scientific and technical research.



Sec.  1502.24  Environmental review and consultation requirements.

    (a) To the fullest extent possible, agencies shall prepare draft 
environmental impact statements concurrent and integrated with 
environmental impact analyses and related surveys and studies required 
by all other Federal environmental review laws and Executive orders 
applicable to the proposed action, including the Fish and Wildlife 
Coordination Act (16 U.S.C. 661 et seq.), the National Historic 
Preservation Act of 1966 (54 U.S.C. 300101 et seq.), and the Endangered 
Species Act of 1973 (16 U.S.C. 1531 et seq.).
    (b) The draft environmental impact statement shall list all Federal 
permits, licenses, and other authorizations that must be obtained in 
implementing the proposal. If it is uncertain whether a Federal permit, 
license, or other authorization is necessary, the draft environmental 
impact statement shall so indicate.



PART 1503_COMMENTING ON ENVIRONMENTAL IMPACT STATEMENTS--Table of Contents



Sec.
1503.1 Inviting comments and requesting information and analyses.
1503.2 Duty to comment.
1503.3 Specificity of comments and information.
1503.4 Response to comments.

    Authority: 42 U.S.C. 4321-4347; 42 U.S.C. 4371-4375; 42 U.S.C. 7609; 
E.O. 11514, 35 FR 4247, 3 CFR, 1966-1970, Comp., p. 902, as amended by 
E.O. 11991, 42 FR 26967, 3 CFR, 1977 Comp., p. 123; E.O. 13807, 82 FR 
40463, 3 CFR, 2017, Comp., p. 369.

    Source: 85 FR 43367, July 16, 2020, unless otherwise noted.



Sec.  1503.1  Inviting comments and requesting information and analyses.

    (a) After preparing a draft environmental impact statement and 
before preparing a final environmental impact statement the agency 
shall:
    (1) Obtain the comments of any Federal agency that has jurisdiction 
by law or special expertise with respect to any environmental impact 
involved or is authorized to develop and enforce environmental 
standards.
    (2) Request the comments of:
    (i) Appropriate State, Tribal, and local agencies that are 
authorized to develop and enforce environmental standards;
    (ii) State, Tribal, or local governments that may be affected by the 
proposed action;
    (iii) Any agency that has requested it receive statements on actions 
of the kind proposed;
    (iv) The applicant, if any; and
    (v) The public, affirmatively soliciting comments in a manner 
designed to inform those persons or organizations who may be interested 
in or affected by the proposed action.
    (3) Invite comment specifically on the submitted alternatives, 
information, and analyses and the summary thereof (Sec.  1502.17 of this 
chapter).
    (b) An agency may request comments on a final environmental impact 
statement before the final decision and set a deadline for providing 
such comments. Other agencies or persons may make comments consistent 
with the time periods under Sec.  1506.11 of this chapter.
    (c) An agency shall provide for electronic submission of public 
comments, with reasonable measures to ensure the comment process is 
accessible to affected persons.



Sec.  1503.2  Duty to comment.

    Cooperating agencies and agencies that are authorized to develop and 
enforce environmental standards shall comment on statements within their 
jurisdiction, expertise, or authority within the time period specified 
for

[[Page 663]]

comment in Sec.  1506.11 of this chapter. A Federal agency may reply 
that it has no comment. If a cooperating agency is satisfied that the 
environmental impact statement adequately reflects its views, it should 
reply that it has no comment.



Sec.  1503.3  Specificity of comments and information.

    (a) To promote informed decision making, comments on an 
environmental impact statement or on a proposed action shall be as 
specific as possible, may address either the adequacy of the statement 
or the merits of the alternatives discussed or both, and shall provide 
as much detail as necessary to meaningfully participate and fully inform 
the agency of the commenter's position. Comments should explain why the 
issues raised are important to the consideration of potential 
environmental impacts and alternatives to the proposed action, as well 
as economic and employment impacts, and other impacts affecting the 
quality of the human environment. Comments should reference the 
corresponding section or page number of the draft environmental impact 
statement, propose specific changes to those parts of the statement, 
where possible, and include or describe the data sources and 
methodologies supporting the proposed changes.
    (b) Comments on the submitted alternatives, information, and 
analyses and summary thereof (Sec.  1502.17 of this chapter) should be 
as specific as possible. Comments and objections of any kind shall be 
raised within the comment period on the draft environmental impact 
statement provided by the agency, consistent with Sec.  1506.11 of this 
chapter. If the agency requests comments on the final environmental 
impact statement before the final decision, consistent with Sec.  
1503.1(b), comments and objections of any kind shall be raised within 
the comment period provided by the agency. Comments and objections of 
any kind not provided within the comment period(s) shall be considered 
unexhausted and forfeited, consistent with Sec.  1500.3(b) of this 
chapter.
    (c) When a participating agency criticizes a lead agency's 
predictive methodology, the participating agency should describe the 
alternative methodology that it prefers and why.
    (d) A cooperating agency shall specify in its comments whether it 
needs additional information to fulfill other applicable environmental 
reviews or consultation requirements and what information it needs. In 
particular, it shall specify any additional information it needs to 
comment adequately on the draft statement's analysis of significant 
site-specific effects associated with the granting or approving by that 
cooperating agency of necessary Federal permits, licenses, or 
authorizations.
    (e) When a cooperating agency with jurisdiction by law specifies 
mitigation measures it considers necessary to allow the agency to grant 
or approve applicable permit, license, or related requirements or 
concurrences, the cooperating agency shall cite to its applicable 
statutory authority.



Sec.  1503.4  Response to comments.

    (a) An agency preparing a final environmental impact statement shall 
consider substantive comments timely submitted during the public comment 
period. The agency may respond to individual comments or groups of 
comments. In the final environmental impact statement, the agency may 
respond by:
    (1) Modifying alternatives including the proposed action.
    (2) Developing and evaluating alternatives not previously given 
serious consideration by the agency.
    (3) Supplementing, improving, or modifying its analyses.
    (4) Making factual corrections.
    (5) Explaining why the comments do not warrant further agency 
response, recognizing that agencies are not required to respond to each 
comment.
    (b) An agency shall append or otherwise publish all substantive 
comments received on the draft statement (or summaries thereof where the 
response has been exceptionally voluminous).
    (c) If changes in response to comments are minor and are confined to 
the responses described in paragraphs (a)(4) and (5) of this section, an 
agency may write any changes on errata sheets and attach the responses 
to the statement instead of rewriting the

[[Page 664]]

draft statement. In such cases, only the comments, the responses, and 
the changes and not the final statement need be published (Sec.  1502.20 
of this chapter). The agency shall file the entire document with a new 
cover sheet with the Environmental Protection Agency as the final 
statement (Sec.  1506.10 of this chapter).



PART 1504_PRE	DECISIONAL REFERRALS TO THE COUNCIL 
OF PROPOSED FEDERAL ACTIONS DETERMINED TO BE ENVIRONMENTALLY 
UNSATISFACTORY--Table of Contents



Sec.
1504.1 Purpose.
1504.2 Criteria for referral.
1504.3 Procedure for referrals and response.

    Authority: 42 U.S.C. 4321-4347; 42 U.S.C. 4371-4375; 42 U.S.C. 7609; 
E.O. 11514, 35 FR 4247, 3 CFR, 1966-1970, Comp., p. 902, as amended by 
E.O. 11991, 42 FR 26967, 3 CFR, 1977 Comp., p. 123; E.O. 13807, 82 FR 
40463, 3 CFR, 2017, Comp., p. 369.

    Source: 85 FR 43367, July 16, 2020, unless otherwise noted.



Sec.  1504.1  Purpose.

    (a) This part establishes procedures for referring to the Council 
Federal interagency disagreements concerning proposed major Federal 
actions that might cause unsatisfactory environmental effects. It 
provides means for early resolution of such disagreements.
    (b) Section 309 of the Clean Air Act (42 U.S.C. 7609) directs the 
Administrator of the Environmental Protection Agency to review and 
comment publicly on the environmental impacts of Federal activities, 
including actions for which agencies prepare environmental impact 
statements. If, after this review, the Administrator determines that the 
matter is ``unsatisfactory from the standpoint of public health or 
welfare or environmental quality,'' section 309 directs that the matter 
be referred to the Council (hereafter ``environmental referrals'').
    (c) Under section 102(2)(C) of NEPA (42 U.S.C. 4332(2)(C)), other 
Federal agencies may prepare similar reviews of environmental impact 
statements, including judgments on the acceptability of anticipated 
environmental impacts. These reviews must be made available to the 
President, the Council, and the public.



Sec.  1504.2  Criteria for referral.

    Environmental referrals should be made to the Council only after 
concerted, timely (as early as practicable in the process), but 
unsuccessful attempts to resolve differences with the lead agency. In 
determining what environmental objections to the matter are appropriate 
to refer to the Council, an agency should weigh potential adverse 
environmental impacts, considering:
    (a) Possible violation of national environmental standards or 
policies;
    (b) Severity;
    (c) Geographical scope;
    (d) Duration;
    (e) Importance as precedents;
    (f) Availability of environmentally preferable alternatives; and
    (g) Economic and technical considerations, including the economic 
costs of delaying or impeding the decision making of the agencies 
involved in the action.



Sec.  1504.3  Procedure for referrals and response.

    (a) A Federal agency making the referral to the Council shall:
    (1) Notify the lead agency at the earliest possible time that it 
intends to refer a matter to the Council unless a satisfactory agreement 
is reached;
    (2) Include such a notification whenever practicable in the 
referring agency's comments on the environmental assessment or draft 
environmental impact statement;
    (3) Identify any essential information that is lacking and request 
that the lead agency make it available at the earliest possible time; 
and
    (4) Send copies of the referring agency's views to the Council.
    (b) The referring agency shall deliver its referral to the Council 
no later than 25 days after the lead agency has made the final 
environmental impact statement available to the Environmental Protection 
Agency, participating agencies, and the public, and in the case of an 
environmental assessment, no later than 25 days after the lead agency 
makes it available. Except when the lead agency grants an extension of 
this

[[Page 665]]

period, the Council will not accept a referral after that date.
    (c) The referral shall consist of:
    (1) A copy of the letter signed by the head of the referring agency 
and delivered to the lead agency informing the lead agency of the 
referral and the reasons for it; and
    (2) A statement supported by factual evidence leading to the 
conclusion that the matter is unsatisfactory from the standpoint of 
public health or welfare or environmental quality. The statement shall:
    (i) Identify any disputed material facts and incorporate (by 
reference if appropriate) agreed upon facts;
    (ii) Identify any existing environmental requirements or policies 
that would be violated by the matter;
    (iii) Present the reasons for the referral;
    (iv) Contain a finding by the agency whether the issue raised is of 
national importance because of the threat to national environmental 
resources or policies or for some other reason;
    (v) Review the steps taken by the referring agency to bring its 
concerns to the attention of the lead agency at the earliest possible 
time; and
    (vi) Give the referring agency's recommendations as to what 
mitigation alternative, further study, or other course of action 
(including abandonment of the matter) are necessary to remedy the 
situation.
    (d) No later than 25 days after the referral to the Council, the 
lead agency may deliver a response to the Council and the referring 
agency. If the lead agency requests more time and gives assurance that 
the matter will not go forward in the interim, the Council may grant an 
extension. The response shall:
    (1) Address fully the issues raised in the referral;
    (2) Be supported by evidence and explanations, as appropriate; and
    (3) Give the lead agency's response to the referring agency's 
recommendations.
    (e) Applicants may provide views in writing to the Council no later 
than the response.
    (f) No later than 25 days after receipt of both the referral and any 
response or upon being informed that there will be no response (unless 
the lead agency agrees to a longer time), the Council may take one or 
more of the following actions:
    (1) Conclude that the process of referral and response has 
successfully resolved the problem.
    (2) Initiate discussions with the agencies with the objective of 
mediation with referring and lead agencies.
    (3) Obtain additional views and information.
    (4) Determine that the issue is not one of national importance and 
request the referring and lead agencies to pursue their decision 
process.
    (5) Determine that the referring and lead agencies should further 
negotiate the issue, and the issue is not appropriate for Council 
consideration until one or more heads of agencies report to the Council 
that the agencies' disagreements are irreconcilable.
    (6) Publish its findings and recommendations (including, where 
appropriate, a finding that the submitted evidence does not support the 
position of an agency).
    (7) When appropriate, submit the referral and the response together 
with the Council's recommendation to the President for action.
    (g) The Council shall take no longer than 60 days to complete the 
actions specified in paragraph (f)(2), (3), or (5) of this section.
    (h) The referral process is not intended to create any private 
rights of action or to be judicially reviewable because any voluntary 
resolutions by the agency parties do not represent final agency action 
and instead are only provisional and dependent on later consistent 
action by the action agencies.



PART 1505_NEPA AND AGENCY DECISION MAKING--Table of Contents



Sec.
1505.1 [Reserved]
1505.2 Record of decision in cases requiring environmental impact 
          statements.
1505.3 Implementing the decision.

    Authority: 42 U.S.C. 4321-4347; 42 U.S.C. 4371-4375; 42 U.S.C. 7609; 
E.O. 11514, 35 FR 4247, 3 CFR, 1966-1970, Comp., p. 902, as amended by 
E.O. 11991, 42 FR 26967, 3 CFR, 1977 Comp., p. 123; and E.O. 13807, 82 
FR 40463, 3 CFR, 2017, Comp., p. 369.

[[Page 666]]


    Source: 85 FR 43369, July 16, 2020, unless otherwise noted.



Sec.  1505.1  [Reserved]



Sec.  1505.2  Record of decision in cases requiring
environmental impact statements.

    (a) At the time of its decision (Sec.  1506.11 of this chapter) or, 
if appropriate, its recommendation to Congress, each agency shall 
prepare and timely publish a concise public record of decision or joint 
record of decision. The record, which each agency may integrate into any 
other record it prepares, shall:
    (1) State the decision.
    (2) Identify alternatives considered by the agency in reaching its 
decision, specifying the alternative or alternatives considered 
environmentally preferable. An agency may discuss preferences among 
alternatives based on relevant factors including economic and technical 
considerations and agency statutory missions. An agency shall identify 
and discuss all such factors, including any essential considerations of 
national policy, that the agency balanced in making its decision and 
state how those considerations entered into its decision.
    (3) State whether the agency has adopted all practicable means to 
avoid or minimize environmental harm from the alternative selected, and 
if not, why the agency did not. The agency shall adopt and summarize, 
where applicable, a monitoring and enforcement program for any 
enforceable mitigation requirements or commitments.
    (b) Informed by the summary of the submitted alternatives, 
information, and analyses in the final environmental impact statement 
(Sec.  1502.17(b) of this chapter), together with any other material in 
the record that he or she determines to be relevant, the decision maker 
shall certify in the record of decision that the agency has considered 
all of the alternatives, information, analyses, and objections submitted 
by State, Tribal, and local governments and public commenters for 
consideration by the lead and cooperating agencies in developing the 
environmental impact statement. Agency environmental impact statements 
certified in accordance with this section are entitled to a presumption 
that the agency has considered the submitted alternatives, information, 
and analyses, including the summary thereof, in the final environmental 
impact statement (Sec.  1502.17(b)).



Sec.  1505.3  Implementing the decision.

    Agencies may provide for monitoring to assure that their decisions 
are carried out and should do so in important cases. Mitigation (Sec.  
1505.2(a)(3)) and other conditions established in the environmental 
impact statement or during its review and committed as part of the 
decision shall be implemented by the lead agency or other appropriate 
consenting agency. The lead agency shall:
    (a) Include appropriate conditions in grants, permits, or other 
approvals.
    (b) Condition funding of actions on mitigation.
    (c) Upon request, inform cooperating or participating agencies on 
progress in carrying out mitigation measures that they have proposed and 
were adopted by the agency making the decision.
    (d) Upon request, publish the results of relevant monitoring.



PART 1506_OTHER REQUIREMENTS OF NEPA--Table of Contents



Sec.
1506.1 Limitations on actions during NEPA process.
1506.2 Elimination of duplication with State, Tribal, and local 
          procedures.
1506.3 Adoption.
1506.4 Combining documents.
1506.5 Agency responsibility for environmental documents.
1506.6 Public involvement.
1506.7 Further guidance.
1506.8 Proposals for legislation.
1506.9 Proposals for regulations.
1506.10 Filing requirements.
1506.11 Timing of agency action.
1506.12 Emergencies.
1506.13 Effective date.

    Authority: 42 U.S.C. 4321-4347; 42 U.S.C. 4371-4375; 42 U.S.C. 7609; 
E.O. 11514, 35 FR 4247, 3 CFR, 1966-1970, Comp., p. 902, as amended by 
E.O. 11991, 42 FR 26967, 3 CFR, 1977 Comp., p. 123; and E.O. 13807, 82 
FR 40463, 3 CFR, 2017, Comp., p. 369.

    Source: 85 FR 43370, July 16, 2020, unless otherwise noted.

[[Page 667]]



Sec.  1506.1  Limitations on actions during NEPA process.

    (a) Except as provided in paragraphs (b) and (c) of this section, 
until an agency issues a finding of no significant impact, as provided 
in Sec.  1501.6 of this chapter, or record of decision, as provided in 
Sec.  1505.2 of this chapter, no action concerning the proposal may be 
taken that would:
    (1) Have an adverse environmental impact; or
    (2) Limit the choice of reasonable alternatives.
    (b) If any agency is considering an application from a non-Federal 
entity and is aware that the applicant is about to take an action within 
the agency's jurisdiction that would meet either of the criteria in 
paragraph (a) of this section, then the agency shall promptly notify the 
applicant that the agency will take appropriate action to ensure that 
the objectives and procedures of NEPA are achieved. This section does 
not preclude development by applicants of plans or designs or 
performance of other activities necessary to support an application for 
Federal, State, Tribal, or local permits or assistance. An agency 
considering a proposed action for Federal funding may authorize such 
activities, including, but not limited to, acquisition of interests in 
land (e.g., fee simple, rights-of-way, and conservation easements), 
purchase of long lead-time equipment, and purchase options made by 
applicants.
    (c) While work on a required programmatic environmental review is in 
progress and the action is not covered by an existing programmatic 
review, agencies shall not undertake in the interim any major Federal 
action covered by the program that may significantly affect the quality 
of the human environment unless such action:
    (1) Is justified independently of the program;
    (2) Is itself accompanied by an adequate environmental review; and
    (3) Will not prejudice the ultimate decision on the program. Interim 
action prejudices the ultimate decision on the program when it tends to 
determine subsequent development or limit alternatives.



Sec.  1506.2  Elimination of duplication with State, Tribal, and local procedures.

    (a) Federal agencies are authorized to cooperate with State, Tribal, 
and local agencies that are responsible for preparing environmental 
documents, including those prepared pursuant to section 102(2)(D) of 
NEPA.
    (b) To the fullest extent practicable unless specifically prohibited 
by law, agencies shall cooperate with State, Tribal, and local agencies 
to reduce duplication between NEPA and State, Tribal, and local 
requirements, including through use of studies, analysis, and decisions 
developed by State, Tribal, or local agencies. Except for cases covered 
by paragraph (a) of this section, such cooperation shall include, to the 
fullest extent practicable:
    (1) Joint planning processes.
    (2) Joint environmental research and studies.
    (3) Joint public hearings (except where otherwise provided by 
statute).
    (4) Joint environmental assessments.
    (c) To the fullest extent practicable unless specifically prohibited 
by law, agencies shall cooperate with State, Tribal, and local agencies 
to reduce duplication between NEPA and comparable State, Tribal, and 
local requirements. Such cooperation shall include, to the fullest 
extent practicable, joint environmental impact statements. In such 
cases, one or more Federal agencies and one or more State, Tribal, or 
local agencies shall be joint lead agencies. Where State or Tribal laws 
or local ordinances have environmental impact statement or similar 
requirements in addition to but not in conflict with those in NEPA, 
Federal agencies may cooperate in fulfilling these requirements, as well 
as those of Federal laws, so that one document will comply with all 
applicable laws.
    (d) To better integrate environmental impact statements into State, 
Tribal, or local planning processes, environmental impact statements 
shall discuss any inconsistency of a proposed action with any approved 
State, Tribal, or local plan or law (whether or not federally 
sanctioned). Where an inconsistency exists, the statement should 
describe the extent to which the agency would reconcile its proposed 
action

[[Page 668]]

with the plan or law. While the statement should discuss any 
inconsistencies, NEPA does not require reconciliation.



Sec.  1506.3  Adoption.

    (a) Generally. An agency may adopt a Federal draft or final 
environmental impact statement, environmental assessment, or portion 
thereof, or categorical exclusion determination provided that the 
statement, assessment, portion thereof, or determination meets the 
standards for an adequate statement, assessment, or determination under 
the regulations in this subchapter.
    (b) Environmental impact statements. (1) If the actions covered by 
the original environmental impact statement and the proposed action are 
substantially the same, the adopting agency shall republish it as a 
final statement consistent with Sec.  1506.10. If the actions are not 
substantially the same, the adopting agency shall treat the statement as 
a draft and republish it, consistent with Sec.  1506.10.
    (2) Notwithstanding paragraph (b)(1) of this section, a cooperating 
agency may adopt in its record of decision without republishing the 
environmental impact statement of a lead agency when, after an 
independent review of the statement, the cooperating agency concludes 
that its comments and suggestions have been satisfied.
    (c) Environmental assessments. If the actions covered by the 
original environmental assessment and the proposed action are 
substantially the same, the adopting agency may adopt the environmental 
assessment in its finding of no significant impact and provide notice 
consistent with Sec.  1501.6 of this chapter.
    (d) Categorical exclusions. An agency may adopt another agency's 
determination that a categorical exclusion applies to a proposed action 
if the action covered by the original categorical exclusion 
determination and the adopting agency's proposed action are 
substantially the same. The agency shall document the adoption.
    (e) Identification of certain circumstances. The adopting agency 
shall specify if one of the following circumstances is present:
    (1) The agency is adopting an assessment or statement that is not 
final within the agency that prepared it.
    (2) The action assessed in the assessment or statement is the 
subject of a referral under part 1504 of this chapter.
    (3) The assessment or statement's adequacy is the subject of a 
judicial action that is not final.



Sec.  1506.4  Combining documents.

    Agencies should combine, to the fullest extent practicable, any 
environmental document with any other agency document to reduce 
duplication and paperwork.



Sec.  1506.5  Agency responsibility for environmental documents.

    (a) Responsibility. The agency is responsible for the accuracy, 
scope (Sec.  1501.9(e) of this chapter), and content of environmental 
documents prepared by the agency or by an applicant or contractor under 
the supervision of the agency.
    (b) Information. An agency may require an applicant to submit 
environmental information for possible use by the agency in preparing an 
environmental document. An agency also may direct an applicant or 
authorize a contractor to prepare an environmental document under the 
supervision of the agency.
    (1) The agency should assist the applicant by outlining the types of 
information required or, for the preparation of environmental documents, 
shall provide guidance to the applicant or contractor and participate in 
their preparation.
    (2) The agency shall independently evaluate the information 
submitted or the environmental document and shall be responsible for its 
accuracy, scope, and contents.
    (3) The agency shall include in the environmental document the names 
and qualifications of the persons preparing environmental documents, and 
conducting the independent evaluation of any information submitted or 
environmental documents prepared by an applicant or contractor, such as 
in the list of preparers for environmental impact statements (Sec.  
1502.18 of this chapter). It is the intent of this paragraph (b)(3) that 
acceptable work not be

[[Page 669]]

redone, but that it be verified by the agency.
    (4) Contractors or applicants preparing environmental assessments or 
environmental impact statements shall submit a disclosure statement to 
the lead agency that specifies any financial or other interest in the 
outcome of the action. Such statement need not include privileged or 
confidential trade secrets or other confidential business information.
    (5) Nothing in this section is intended to prohibit any agency from 
requesting any person, including the applicant, to submit information to 
it or to prohibit any person from submitting information to any agency 
for use in preparing environmental documents.



Sec.  1506.6  Public involvement.

    Agencies shall:
    (a) Make diligent efforts to involve the public in preparing and 
implementing their NEPA procedures (Sec.  1507.3 of this chapter).
    (b) Provide public notice of NEPA-related hearings, public meetings, 
and other opportunities for public involvement, and the availability of 
environmental documents so as to inform those persons and agencies who 
may be interested or affected by their proposed actions. When selecting 
appropriate methods for providing public notice, agencies shall consider 
the ability of affected persons and agencies to access electronic media.
    (1) In all cases, the agency shall notify those who have requested 
notice on an individual action.
    (2) In the case of an action with effects of national concern, 
notice shall include publication in the Federal Register. An agency may 
notify organizations that have requested regular notice.
    (3) In the case of an action with effects primarily of local 
concern, the notice may include:
    (i) Notice to State, Tribal, and local agencies that may be 
interested or affected by the proposed action.
    (ii) Notice to interested or affected State, Tribal, and local 
governments.
    (iii) Following the affected State or Tribe's public notice 
procedures for comparable actions.
    (iv) Publication in local newspapers (in papers of general 
circulation rather than legal papers).
    (v) Notice through other local media.
    (vi) Notice to potentially interested community organizations 
including small business associations.
    (vii) Publication in newsletters that may be expected to reach 
potentially interested persons.
    (viii) Direct mailing to owners and occupants of nearby or affected 
property.
    (ix) Posting of notice on and off site in the area where the action 
is to be located.
    (x) Notice through electronic media (e.g., a project or agency 
website, email, or social media).
    (c) Hold or sponsor public hearings, public meetings, or other 
opportunities for public involvement whenever appropriate or in 
accordance with statutory requirements applicable to the agency. 
Agencies may conduct public hearings and public meetings by means of 
electronic communication except where another format is required by law. 
When selecting appropriate methods for public involvement, agencies 
shall consider the ability of affected entities to access electronic 
media.
    (d) Solicit appropriate information from the public.
    (e) Explain in its procedures where interested persons can get 
information or status reports on environmental impact statements and 
other elements of the NEPA process.
    (f) Make environmental impact statements, the comments received, and 
any underlying documents available to the public pursuant to the 
provisions of the Freedom of Information Act, as amended (5 U.S.C. 552).



Sec.  1506.7  Further guidance.

    (a) The Council may provide further guidance concerning NEPA and its 
procedures consistent with Executive Order 13807, Establishing 
Discipline and Accountability in the Environmental Review and Permitting 
Process for Infrastructure Projects (August 5, 2017), Executive Order 
13891, Promoting the Rule of Law Through Improved Agency Guidance 
Documents (October 9, 2019), and any other applicable Executive orders.

[[Page 670]]

    (b) To the extent that Council guidance issued prior to September 
14, 2020 is in conflict with this subchapter, the provisions of this 
subchapter apply.



Sec.  1506.8  Proposals for legislation.

    (a) When developing legislation, agencies shall integrate the NEPA 
process for proposals for legislation significantly affecting the 
quality of the human environment with the legislative process of the 
Congress. Technical drafting assistance does not by itself constitute a 
legislative proposal. Only the agency that has primary responsibility 
for the subject matter involved will prepare a legislative environmental 
impact statement.
    (b) A legislative environmental impact statement is the detailed 
statement required by law to be included in an agency's recommendation 
or report on a legislative proposal to Congress. A legislative 
environmental impact statement shall be considered part of the formal 
transmittal of a legislative proposal to Congress; however, it may be 
transmitted to Congress up to 30 days later in order to allow time for 
completion of an accurate statement that can serve as the basis for 
public and Congressional debate. The statement must be available in time 
for Congressional hearings and deliberations.
    (c) Preparation of a legislative environmental impact statement 
shall conform to the requirements of the regulations in this subchapter, 
except as follows:
    (1) There need not be a scoping process.
    (2) Agencies shall prepare the legislative statement in the same 
manner as a draft environmental impact statement and need not prepare a 
final statement unless any of the following conditions exist. In such 
cases, the agency shall prepare and publish the statements consistent 
with Sec. Sec.  1503.1 of this chapter and 1506.11:
    (i) A Congressional committee with jurisdiction over the proposal 
has a rule requiring both draft and final environmental impact 
statements.
    (ii) The proposal results from a study process required by statute 
(such as those required by the Wild and Scenic Rivers Act (16 U.S.C. 
1271 et seq.)).
    (iii) Legislative approval is sought for Federal or federally 
assisted construction or other projects that the agency recommends be 
located at specific geographic locations. For proposals requiring an 
environmental impact statement for the acquisition of space by the 
General Services Administration, a draft statement shall accompany the 
Prospectus or the 11(b) Report of Building Project Surveys to the 
Congress, and a final statement shall be completed before site 
acquisition.
    (iv) The agency decides to prepare draft and final statements.
    (d) Comments on the legislative statement shall be given to the lead 
agency, which shall forward them along with its own responses to the 
Congressional committees with jurisdiction.



Sec.  1506.9  Proposals for regulations.

    Where the proposed action is the promulgation of a rule or 
regulation, procedures and documentation pursuant to other statutory or 
Executive order requirements may satisfy one or more requirements of 
this subchapter. When a procedure or document satisfies one or more 
requirements of this subchapter, the agency may substitute it for the 
corresponding requirements in this subchapter and need not carry out 
duplicative procedures or documentation. Agencies shall identify which 
corresponding requirements in this subchapter are satisfied and consult 
with the Council to confirm such determinations.



Sec.  1506.10  Filing requirements.

    (a) Agencies shall file environmental impact statements together 
with comments and responses with the Environmental Protection Agency 
(EPA), Office of Federal Activities, consistent with EPA's procedures.
    (b) Agencies shall file statements with the EPA no earlier than they 
are also transmitted to participating agencies and made available to the 
public. EPA may issue guidelines to agencies to implement its 
responsibilities under this section and Sec.  1506.11.



Sec.  1506.11  Timing of agency action.

    (a) The Environmental Protection Agency shall publish a notice in 
the

[[Page 671]]

Federal Register each week of the environmental impact statements filed 
since its prior notice. The minimum time periods set forth in this 
section are calculated from the date of publication of this notice.
    (b) Unless otherwise provided by law, including statutory provisions 
for combining a final environmental impact statement and record of 
decision, Federal agencies may not make or issue a record of decision 
under Sec.  1505.2 of this chapter for the proposed action until the 
later of the following dates:
    (1) 90 days after publication of the notice described in paragraph 
(a) of this section for a draft environmental impact statement.
    (2) 30 days after publication of the notice described in paragraph 
(a) of this section for a final environmental impact statement.
    (c) An agency may make an exception to the rule on timing set forth 
in paragraph (b) of this section for a proposed action in the following 
circumstances:
    (1) Some agencies have a formally established appeal process after 
publication of the final environmental impact statement that allows 
other agencies or the public to take appeals on a decision and make 
their views known. In such cases where a real opportunity exists to 
alter the decision, the agency may make and record the decision at the 
same time it publishes the environmental impact statement. This means 
that the period for appeal of the decision and the 30-day period set 
forth in paragraph (b)(2) of this section may run concurrently. In such 
cases, the environmental impact statement shall explain the timing and 
the public's right of appeal and provide notification consistent with 
Sec.  1506.10; or
    (2) An agency engaged in rulemaking under the Administrative 
Procedure Act or other statute for the purpose of protecting the public 
health or safety may waive the time period in paragraph (b)(2) of this 
section, publish a decision on the final rule simultaneously with 
publication of the notice of the availability of the final environmental 
impact statement, and provide notification consistent with Sec.  
1506.10, as described in paragraph (a) of this section.
    (d) If an agency files the final environmental impact statement 
within 90 days of the filing of the draft environmental impact statement 
with the Environmental Protection Agency, the decision-making period and 
the 90-day period may run concurrently. However, subject to paragraph 
(e) of this section, agencies shall allow at least 45 days for comments 
on draft statements.
    (e) The lead agency may extend the minimum periods in paragraph (b) 
of this section and provide notification consistent with Sec.  1506.10. 
Upon a showing by the lead agency of compelling reasons of national 
policy, the Environmental Protection Agency may reduce the minimum 
periods and, upon a showing by any other Federal agency of compelling 
reasons of national policy, also may extend the minimum periods, but 
only after consultation with the lead agency. The lead agency may modify 
the minimum periods when necessary to comply with other specific 
statutory requirements. (Sec.  1507.3(f)(2) of this chapter) Failure to 
file timely comments shall not be a sufficient reason for extending a 
period. If the lead agency does not concur with the extension of time, 
EPA may not extend it for more than 30 days. When the Environmental 
Protection Agency reduces or extends any period of time it shall notify 
the Council.



Sec.  1506.12  Emergencies.

    Where emergency circumstances make it necessary to take an action 
with significant environmental impact without observing the provisions 
of the regulations in this subchapter, the Federal agency taking the 
action should consult with the Council about alternative arrangements 
for compliance with section 102(2)(C) of NEPA. Agencies and the Council 
will limit such arrangements to actions necessary to control the 
immediate impacts of the emergency. Other actions remain subject to NEPA 
review.



Sec.  1506.13  Effective date.

    The regulations in this subchapter apply to any NEPA process begun 
after September 14, 2020. An agency may

[[Page 672]]

apply the regulations in this subchapter to ongoing activities and 
environmental documents begun before September 14, 2020.



PART 1507_AGENCY COMPLIANCE--Table of Contents



Sec.
1507.1 Compliance.
1507.2 Agency capability to comply.
1507.3 Agency NEPA procedures.
1507.4 Agency NEPA program information.

    Authority: 42 U.S.C. 4321-4347; 42 U.S.C. 4371-4375; 42 U.S.C. 7609; 
and E.O. 11514, 35 FR 4247, 3 CFR, 1966-1970, Comp., p. 902, as amended 
by E.O. 11991, 42 FR 26967, 3 CFR, 1977 Comp., p. 123.

    Source: 85 FR 43373, July 16, 2020, unless otherwise noted.



Sec.  1507.1  Compliance.

    All agencies of the Federal Government shall comply with the 
regulations in this subchapter.



Sec.  1507.2  Agency capability to comply.

    Each agency shall be capable (in terms of personnel and other 
resources) of complying with the requirements of NEPA and the 
regulations in this subchapter. Such compliance may include use of the 
resources of other agencies, applicants, and other participants in the 
NEPA process, but the agency using the resources shall itself have 
sufficient capability to evaluate what others do for it and account for 
the contributions of others. Agencies shall:
    (a) Fulfill the requirements of section 102(2)(A) of NEPA to utilize 
a systematic, interdisciplinary approach that will ensure the integrated 
use of the natural and social sciences and the environmental design arts 
in planning and in decision making that may have an impact on the human 
environment. Agencies shall designate a senior agency official to be 
responsible for overall review of agency NEPA compliance, including 
resolving implementation issues.
    (b) Identify methods and procedures required by section 102(2)(B) of 
NEPA to ensure that presently unquantified environmental amenities and 
values may be given appropriate consideration.
    (c) Prepare adequate environmental impact statements pursuant to 
section 102(2)(C) of NEPA and cooperate on the development of statements 
in the areas where the agency has jurisdiction by law or special 
expertise or is authorized to develop and enforce environmental 
standards.
    (d) Study, develop, and describe alternatives to recommended courses 
of action in any proposal that involves unresolved conflicts concerning 
alternative uses of available resources, consistent with section 
102(2)(E) of NEPA.
    (e) Comply with the requirements of section 102(2)(H) of NEPA that 
the agency initiate and utilize ecological information in the planning 
and development of resource-oriented projects.
    (f) Fulfill the requirements of sections 102(2)(F), 102(2)(G), and 
102(2)(I), of NEPA, Executive Order 11514, Protection and Enhancement of 
Environmental Quality, section 2, as amended by Executive Order 11991, 
Relating to Protection and Enhancement of Environmental Quality, and 
Executive Order 13807, Establishing Discipline and Accountability in the 
Environmental Review and Permitting for Infrastructure Projects.



Sec.  1507.3  Agency NEPA procedures.

    (a) The Council has determined that the categorical exclusions 
contained in agency NEPA procedures as of September 14, 2020, are 
consistent with this subchapter.
    (b) No more than 36 months after September 14, 2020, or 9 months 
after the establishment of an agency, whichever comes later, each agency 
shall develop or revise, as necessary, proposed procedures to implement 
the regulations in this subchapter. When the agency is a department, it 
may be efficient for major subunits (with the consent of the department) 
to adopt their own procedures.
    (1) Each agency shall consult with the Council while developing or 
revising its proposed procedures and before publishing them in the 
Federal Register for comment. Agencies with similar programs should 
consult with each other and the Council to coordinate their procedures, 
especially for programs requesting similar information from applicants.

[[Page 673]]

    (2) Agencies shall provide an opportunity for public review and 
review by the Council for conformity with the Act and the regulations in 
this subchapter before adopting their final procedures. The Council 
shall complete its review within 30 days of the receipt of the proposed 
final procedures. Once in effect, the agency shall publish its NEPA 
procedures and ensure that they are readily available to the public.
    (c) Agencies shall adopt, as necessary, agency NEPA procedures to 
improve agency efficiency and ensure that agencies make decisions in 
accordance with the Act's procedural requirements. Such procedures shall 
include:
    (1) Designating the major decision points for the agency's principal 
programs likely to have a significant effect on the human environment 
and assuring that the NEPA process begins at the earliest reasonable 
time, consistent with Sec.  1501.2 of this chapter, and aligns with the 
corresponding decision points.
    (2) Requiring that relevant environmental documents, comments, and 
responses be part of the record in formal rulemaking or adjudicatory 
proceedings.
    (3) Requiring that relevant environmental documents, comments, and 
responses accompany the proposal through existing agency review 
processes so that decision makers use the statement in making decisions.
    (4) Requiring that the alternatives considered by the decision maker 
are encompassed by the range of alternatives discussed in the relevant 
environmental documents and that the decision maker consider the 
alternatives described in the environmental documents. If another 
decision document accompanies the relevant environmental documents to 
the decision maker, agencies are encouraged to make available to the 
public before the decision is made any part of that document that 
relates to the comparison of alternatives.
    (5) Requiring the combination of environmental documents with other 
agency documents. Agencies may designate and rely on one or more 
procedures or documents under other statutes or Executive orders as 
satisfying some or all of the requirements in this subchapter, and 
substitute such procedures and documentation to reduce duplication. When 
an agency substitutes one or more procedures or documents for the 
requirements in this subchapter, the agency shall identify the 
respective requirements that are satisfied.
    (d) Agency procedures should identify those activities or decisions 
that are not subject to NEPA, including:
    (1) Activities or decisions expressly exempt from NEPA under another 
statute;
    (2) Activities or decisions where compliance with NEPA would clearly 
and fundamentally conflict with the requirements of another statute;
    (3) Activities or decisions where compliance with NEPA would be 
inconsistent with Congressional intent expressed in another statute;
    (4) Activities or decisions that are non-major Federal actions;
    (5) Activities or decisions that are non-discretionary actions, in 
whole or in part, for which the agency lacks authority to consider 
environmental effects as part of its decision-making process; and
    (6) Actions where the agency has determined that another statute's 
requirements serve the function of agency compliance with the Act.
    (e) Agency procedures shall comply with the regulations in this 
subchapter except where compliance would be inconsistent with statutory 
requirements and shall include:
    (1) Those procedures required by Sec. Sec.  1501.2(b)(4) (assistance 
to applicants) and 1506.6(e) of this chapter (status information).
    (2) Specific criteria for and identification of those typical 
classes of action:
    (i) Which normally do require environmental impact statements.
    (ii) Which normally do not require either an environmental impact 
statement or an environmental assessment and do not have a significant 
effect on the human environment (categorical exclusions (Sec.  1501.4 of 
this chapter)). Any procedures under this section shall provide for 
extraordinary circumstances in which a normally excluded action may have 
a significant environmental effect. Agency NEPA

[[Page 674]]

procedures shall identify when documentation of a categorical exclusion 
determination is required.
    (iii) Which normally require environmental assessments but not 
necessarily environmental impact statements.
    (3) Procedures for introducing a supplement to an environmental 
assessment or environmental impact statement into its formal 
administrative record, if such a record exists.
    (f) Agency procedures may:
    (1) Include specific criteria for providing limited exceptions to 
the provisions of the regulations in this subchapter for classified 
proposals. These are proposed actions that are specifically authorized 
under criteria established by an Executive order or statute to be kept 
secret in the interest of national defense or foreign policy and are in 
fact properly classified pursuant to such Executive order or statute. 
Agencies may safeguard and restrict from public dissemination 
environmental assessments and environmental impact statements that 
address classified proposals in accordance with agencies' own 
regulations applicable to classified information. Agencies should 
organize these documents so that classified portions are included as 
annexes, so that the agencies can make the unclassified portions 
available to the public.
    (2) Provide for periods of time other than those presented in Sec.  
1506.11 of this chapter when necessary to comply with other specific 
statutory requirements, including requirements of lead or cooperating 
agencies.
    (3) Provide that, where there is a lengthy period between the 
agency's decision to prepare an environmental impact statement and the 
time of actual preparation, the agency may publish the notice of intent 
required by Sec.  1501.9(d) of this chapter at a reasonable time in 
advance of preparation of the draft statement. Agency procedures shall 
provide for publication of supplemental notices to inform the public of 
a pause in its preparation of an environmental impact statement and for 
any agency decision to withdraw its notice of intent to prepare an 
environmental impact statement.
    (4) Adopt procedures to combine its environmental assessment process 
with its scoping process.
    (5) Establish a process that allows the agency to use a categorical 
exclusion listed in another agency's NEPA procedures after consulting 
with that agency to ensure the use of the categorical exclusion is 
appropriate. The process should ensure documentation of the consultation 
and identify to the public those categorical exclusions the agency may 
use for its proposed actions. Then, the agency may apply the categorical 
exclusion to its proposed actions.

[85 FR 43373, July 16, 2020, as amended at 87 FR 23469, Apr. 20, 2022]



Sec.  1507.4  Agency NEPA program information.

    (a) To allow agencies and the public to efficiently and effectively 
access information about NEPA reviews, agencies shall provide for agency 
websites or other means to make available environmental documents, 
relevant notices, and other relevant information for use by agencies, 
applicants, and interested persons. Such means of publication may 
include:
    (1) Agency planning and environmental documents that guide agency 
management and provide for public involvement in agency planning 
processes;
    (2) A directory of pending and final environmental documents;
    (3) Agency policy documents, orders, terminology, and explanatory 
materials regarding agency decision-making processes;
    (4) Agency planning program information, plans, and planning tools; 
and
    (5) A database searchable by geographic information, document 
status, document type, and project type.
    (b) Agencies shall provide for efficient and effective interagency 
coordination of their environmental program websites, including use of 
shared databases or application programming interface, in their 
implementation of NEPA and related authorities.



PART 1508_DEFINITIONS--Table of Contents



Sec.
1508.1 Definitions.
1508.2 [Reserved]

    Authority: 42 U.S.C. 4321-4347; 42 U.S.C. 4371-4375; 42 U.S.C. 7609; 
and E.O. 11514, 35 FR

[[Page 675]]

4247, 3 CFR, 1966-1970, Comp., p. 902, as amended by E.O. 11991, 42 FR 
26967, 3 CFR, 1977 Comp., p. 123.

    Source: 85 FR 43374, July 16, 2020, unless otherwise noted.



Sec.  1508.1  Definitions.

    The following definitions apply to the regulations in this 
subchapter. Federal agencies shall use these terms uniformly throughout 
the Federal Government.
    (a) Act or NEPA means the National Environmental Policy Act, as 
amended (42 U.S.C. 4321, et seq.).
    (b) Affecting means will or may have an effect on.
    (c) Authorization means any license, permit, approval, finding, 
determination, or other administrative decision issued by an agency that 
is required or authorized under Federal law in order to implement a 
proposed action.
    (d) Categorical exclusion means a category of actions that the 
agency has determined, in its agency NEPA procedures (Sec.  1507.3 of 
this chapter), normally do not have a significant effect on the human 
environment.
    (e) Cooperating agency means any Federal agency (and a State, 
Tribal, or local agency with agreement of the lead agency) other than a 
lead agency that has jurisdiction by law or special expertise with 
respect to any environmental impact involved in a proposal (or a 
reasonable alternative) for legislation or other major Federal action 
that may significantly affect the quality of the human environment.
    (f) Council means the Council on Environmental Quality established 
by title II of the Act.
    (g) Effects or impacts means changes to the human environment from 
the proposed action or alternatives that are reasonably foreseeable and 
include the following:
    (1) Direct effects, which are caused by the action and occur at the 
same time and place.
    (2) Indirect effects, which are caused by the action and are later 
in time or farther removed in distance, but are still reasonably 
foreseeable. Indirect effects may include growth inducing effects and 
other effects related to induced changes in the pattern of land use, 
population density or growth rate, and related effects on air and water 
and other natural systems, including ecosystems.
    (3) Cumulative effects, which are effects on the environment that 
result from the incremental effects of the action when added to the 
effects of other past, present, and reasonably foreseeable actions 
regardless of what agency (Federal or non-Federal) or person undertakes 
such other actions. Cumulative effects can result from individually 
minor but collectively significant actions taking place over a period of 
time.
    (4) Effects include ecological (such as the effects on natural 
resources and on the components, structures, and functioning of affected 
ecosystems), aesthetic, historic, cultural, economic, social, or health, 
whether direct, indirect, or cumulative. Effects may also include those 
resulting from actions which may have both beneficial and detrimental 
effects, even if on balance the agency believes that the effects will be 
beneficial.
    (h) Environmental assessment means a concise public document 
prepared by a Federal agency to aid an agency's compliance with the Act 
and support its determination of whether to prepare an environmental 
impact statement or a finding of no significant impact, as provided in 
Sec.  1501.6 of this chapter.
    (i) Environmental document means an environmental assessment, 
environmental impact statement, finding of no significant impact, or 
notice of intent.
    (j) Environmental impact statement means a detailed written 
statement as required by section 102(2)(C) of NEPA.
    (k) Federal agency means all agencies of the Federal Government. It 
does not mean the Congress, the Judiciary, or the President, including 
the performance of staff functions for the President in his Executive 
Office. For the purposes of the regulations in this subchapter, Federal 
agency also includes States, units of general local government, and 
Tribal governments assuming NEPA responsibilities from a Federal agency 
pursuant to statute.
    (l) Finding of no significant impact means a document by a Federal 
agency briefly presenting the reasons why an action, not otherwise 
categorically excluded (Sec.  1501.4 of this chapter), will not

[[Page 676]]

have a significant effect on the human environment and for which an 
environmental impact statement therefore will not be prepared.
    (m) Human environment means comprehensively the natural and physical 
environment and the relationship of present and future generations of 
Americans with that environment. (See also the definition of ``effects'' 
in paragraph (g) of this section.)
    (n) Jurisdiction by law means agency authority to approve, veto, or 
finance all or part of the proposal.
    (o) Lead agency means the agency or agencies, in the case of joint 
lead agencies, preparing or having taken primary responsibility for 
preparing the environmental impact statement.
    (p) Legislation means a bill or legislative proposal to Congress 
developed by a Federal agency, but does not include requests for 
appropriations or legislation recommended by the President.
    (q) Major Federal action or action means an activity or decision 
subject to Federal control and responsibility subject to the following:
    (1) Major Federal action does not include the following activities 
or decisions:
    (i) Extraterritorial activities or decisions, which means agency 
activities or decisions with effects located entirely outside of the 
jurisdiction of the United States;
    (ii) Activities or decisions that are non-discretionary and made in 
accordance with the agency's statutory authority;
    (iii) Activities or decisions that do not result in final agency 
action under the Administrative Procedure Act or other statute that also 
includes a finality requirement;
    (iv) Judicial or administrative civil or criminal enforcement 
actions;
    (v) Funding assistance solely in the form of general revenue sharing 
funds with no Federal agency control over the subsequent use of such 
funds;
    (vi) Non-Federal projects with minimal Federal funding or minimal 
Federal involvement where the agency does not exercise sufficient 
control and responsibility over the outcome of the project; and
    (vii) Loans, loan guarantees, or other forms of financial assistance 
where the Federal agency does not exercise sufficient control and 
responsibility over the effects of such assistance (for example, action 
does not include farm ownership and operating loan guarantees by the 
Farm Service Agency pursuant to 7 U.S.C. 1925 and 1941 through 1949 and 
business loan guarantees by the Small Business Administration pursuant 
to 15 U.S.C. 636(a), 636(m), and 695 through 697g).
    (2) Major Federal actions may include new and continuing activities, 
including projects and programs entirely or partly financed, assisted, 
conducted, regulated, or approved by Federal agencies; new or revised 
agency rules, regulations, plans, policies, or procedures; and 
legislative proposals (Sec.  1506.8 of this chapter).
    (3) Major Federal actions tend to fall within one of the following 
categories:
    (i) Adoption of official policy, such as rules, regulations, and 
interpretations adopted under the Administrative Procedure Act, 5 U.S.C. 
551 et seq. or other statutes; implementation of treaties and 
international conventions or agreements, including those implemented 
pursuant to statute or regulation; formal documents establishing an 
agency's policies which will result in or substantially alter agency 
programs.
    (ii) Adoption of formal plans, such as official documents prepared 
or approved by Federal agencies, which prescribe alternative uses of 
Federal resources, upon which future agency actions will be based.
    (iii) Adoption of programs, such as a group of concerted actions to 
implement a specific policy or plan; systematic and connected agency 
decisions allocating agency resources to implement a specific statutory 
program or executive directive.
    (iv) Approval of specific projects, such as construction or 
management activities located in a defined geographic area. Projects 
include actions approved by permit or other regulatory decision as well 
as Federal and federally assisted activities.
    (r) Matter includes for purposes of part 1504 of this chapter:
    (1) With respect to the Environmental Protection Agency, any 
proposed legislation, project, action or regulation as those terms are 
used in

[[Page 677]]

section 309(a) of the Clean Air Act (42 U.S.C. 7609).
    (2) With respect to all other agencies, any proposed major Federal 
action to which section 102(2)(C) of NEPA applies.
    (s) Mitigation means measures that avoid, minimize, or compensate 
for effects caused by a proposed action or alternatives as described in 
an environmental document or record of decision and that have a nexus to 
those effects. While NEPA requires consideration of mitigation, it does 
not mandate the form or adoption of any mitigation. Mitigation includes:
    (1) Avoiding the impact altogether by not taking a certain action or 
parts of an action.
    (2) Minimizing impacts by limiting the degree or magnitude of the 
action and its implementation.
    (3) Rectifying the impact by repairing, rehabilitating, or restoring 
the affected environment.
    (4) Reducing or eliminating the impact over time by preservation and 
maintenance operations during the life of the action.
    (5) Compensating for the impact by replacing or providing substitute 
resources or environments.
    (t) NEPA process means all measures necessary for compliance with 
the requirements of section 2 and title I of NEPA.
    (u) Notice of intent means a public notice that an agency will 
prepare and consider an environmental impact statement.
    (v) Page means 500 words and does not include explanatory maps, 
diagrams, graphs, tables, and other means of graphically displaying 
quantitative or geospatial information.
    (w) Participating agency means a Federal, State, Tribal, or local 
agency participating in an environmental review or authorization of an 
action.
    (x) Proposal means a proposed action at a stage when an agency has a 
goal, is actively preparing to make a decision on one or more 
alternative means of accomplishing that goal, and can meaningfully 
evaluate its effects. A proposal may exist in fact as well as by agency 
declaration that one exists.
    (y) Publish and publication mean methods found by the agency to 
efficiently and effectively make environmental documents and information 
available for review by interested persons, including electronic 
publication, and adopted by agency NEPA procedures pursuant to Sec.  
1507.3 of this chapter.
    (z) Reasonable alternatives means a reasonable range of alternatives 
that are technically and economically feasible, and meet the purpose and 
need for the proposed action.
    (aa) Reasonably foreseeable means sufficiently likely to occur such 
that a person of ordinary prudence would take it into account in 
reaching a decision.
    (bb) Referring agency means the Federal agency that has referred any 
matter to the Council after a determination that the matter is 
unsatisfactory from the standpoint of public health or welfare or 
environmental quality.
    (cc) Scope consists of the range of actions, alternatives, and 
impacts to be considered in an environmental impact statement. The scope 
of an individual statement may depend on its relationships to other 
statements (Sec.  1501.11 of this chapter).
    (dd) Senior agency official means an official of assistant secretary 
rank or higher (or equivalent) that is designated for overall agency 
NEPA compliance, including resolving implementation issues.
    (ee) Special expertise means statutory responsibility, agency 
mission, or related program experience.
    (ff) Tiering refers to the coverage of general matters in broader 
environmental impact statements or environmental assessments (such as 
national program or policy statements) with subsequent narrower 
statements or environmental analyses (such as regional or basin-wide 
program statements or ultimately site-specific statements) incorporating 
by reference the general discussions and concentrating solely on the 
issues specific to the statement subsequently prepared.

[85 FR 43378, July 16, 2020, as amended at 87 FR 23469, Apr. 20, 2022]



Sec.  1508.2  [Reserved]

[[Page 679]]



          SUBCHAPTER B_ADMINISTRATIVE PROCEDURES AND OPERATIONS





PART 1515_FREEDOM OF INFORMATION ACT PROCEDURES--Table of Contents



                                 Purpose

Sec.
1515.1 FOIA procedures.

                           Organization of CEQ

1515.2 About the Council on Environmental Quality (CEQ).
1515.3 CEQ organization.
1515.4 CEQ FOIA Officials.

                    Procedures for Requesting Records

1515.5 Making a Freedom of Information Act request.
1515.6 CEQ's response to a request.
1515.7 Expedited processing.
1515.8 Appeals.
1515.9 Extending CEQ's time to respond.

                       Availability of Information

1515.10 Obtaining available information.

                                  Costs

1515.11 Definitions.
1515.12 Fees in general.
1515.13 Fees for categories of requesters.
1515.14 Other charges.
1515.15 Payment and waiver.
1515.16 Other rights and services.
1515.17-1515.19 [Reserved]

    Authority: 5 U.S.C. 552, as amended by Pub. L. 93-502, Pub. L. 99-
570, Pub. L. 104-231, Pub. L. 110-175; E.O. 13392; Pres. Mem. 74 FR 
4685. Source: 42 FR 65158, Dec. 30, 1977, unless otherwise noted.

    Source: 75 FR 48590, Aug. 11, 2010, unless otherwise noted.

                                 Purpose



Sec.  1515.1  FOIA procedures.

    The Freedom of Information Act (5 U.S.C. 552), as amended, commonly 
known as FOIA, is a Federal law that creates a procedure for any person 
to request documents and other records from United States Government 
agencies. The law requires every Federal agency to make available to the 
public the material requested, unless the material falls under one of 
the limited exemptions stated in Section 552(b) of the Act. These 
procedures explain how the Council on Environmental Quality (CEQ)--one 
of several agencies in the Executive Office of the President--will carry 
out the FOIA. They are written from the standpoint of a FOIA requester 
and should be read together with the FOIA, which provides additional 
information about access to records maintained by CEQ. This information 
is furnished for the guidance of the public and in compliance with the 
requirements of Section 552 of title 5, United States Code, as amended.

                           Organization of CEQ



Sec.  1515.2  About the Council on Environmental Quality (CEQ).

    The Council on Environmental Quality (``CEQ'' or ``the Council'') 
was created by the National Environmental Policy Act of 1969, as amended 
(42 U.S.C. 4321 through 4347). The Council's authority is primarily 
derived from that Act, the Environmental Quality Improvement Act of 
1970, as amended (42 U.S.C. 4371-4374), Reorganization Plan No. 1 of 
1977 (July 15, 1977), and Executive Order 11514, ``Protection and 
Enhancement of Environmental Quality,'' March 5, 1970, as amended by 
Executive Order 11991, May 24, 1977.



Sec.  1515.3  CEQ organization.

    (a) The Council is made up of a Chair appointed by the President and 
subject to approval by the Senate who serves in a full-time capacity. 
Congress has allowed CEQ to consist of a Council of one member who 
serves as Chairman or Chair.
    (b) The National Environmental Policy Act and the Environmental 
Quality Improvement Act give the Council the authority to hire any 
officers and staff that may be necessary to carry out responsibilities 
and functions specified in these two Acts. Also, the use of consultants 
and experts is permitted.
    (c) In addition to the Chair, the Council has program and legal 
staff.
    (d) The Council has no field or regional offices.
    (e) The Council is located at 722 Jackson Place NW., Washington, DC 
20503. Office hours are 9 a.m.-5:30 p.m.,

[[Page 680]]

Monday through Friday, except Federal holidays. To meet with any of the 
staff, please write or phone ahead for an appointment. The main number 
is 202-456-6224.



Sec.  1515.4  CEQ FOIA Officials.

    (a) The Chair shall appoint a Chief Freedom of Information Act 
Officer (Chief FOIA Officer) who is responsible for overseeing the 
Council's administration of the Freedom of Information Act and for 
receiving, routing and overseeing the processing of all Freedom of 
Information requests as set forth in these regulations. The Chair shall 
appoint an Appeals Officer, who is responsible for processing and acting 
upon any appeals and may designate one or more CEQ officials, as 
appropriate, as FOIA Officers authorized to oversee and process FOIA 
requests. The Chief FOIA Officer may serve as the Appeals Officer.
    (b) The Chief FOIA officer shall designate a FOIA Public Liaison who 
is the supervisory official to whom a FOIA requester can raise concerns 
about the service the FOIA requester has received from the CEQ FOIA 
Center, described in Section 1515.5(a), following an initial response 
from the staff of the CEQ FOIA Center staff. The FOIA Public Liaison 
shall assist, as appropriate, in reducing delays and increasing 
understanding of the status of requests. The Chief FOIA officer shall 
also designate a CEQ FOIA Officer responsible for overseeing CEQ's day-
to-day administration of the FOIA and for receiving, routing, and 
overseeing the processing of all FOIA requests.

                    Procedures for Requesting Records



Sec.  1515.5  Making a Freedom of Information Act request.

    (a) Availability of records. The Council maintains a World Wide Web 
site, http://www.whitehouse.gov /administration/eop/ceq, and an online 
Freedom of Information Act Requester Service Center (``Center''), http:/
/www.whitehouse.gov /administration/eop/ceq/foia. From the Center, a 
requester can find contact information regarding the CEQ's FOIA Public 
Liaison, as defined in Section 1515.4(b), and access CEQ's Online 
Reading Room where CEQ makes available records pertaining to matters 
within the scope of 5 U.S.C. 552(a)(2), as amended, and environmental 
issues and other documents that, because of the nature of their subject 
matter, are likely to be the subject of FOIA requests. To save both time 
and money, CEQ strongly urges requesters to review documents currently 
available from the Center's Online Reading Room before submitting a 
request.
    (b) Requesting information from the Council. (1) Requesters must 
make a Freedom of Information Act request in writing. For quickest 
possible handling, it should be sent via e-mail to: [email protected] 
and must include in the subject line of the e-mail message: ``Freedom of 
Information Act Request.'' Written requests may also be faxed to (202) 
456-0753 or addressed and mailed to: Council on Environmental Quality, 
Executive Office of the President, 722 Jackson Place NW., Washington, DC 
20503. Requesters should mark both the request letter and the envelope 
``Freedom of Information Act Request'' and include their name, address, 
and sufficient contact information to allow follow up regarding the 
scope and status of your request.
    (2) The request should identify or reasonably describe the desired 
record. It should be as specific as possible, so that the item can be 
readily found. Blanket requests, such as requests for ``all materials 
relating to'' a specified subject are not recommended. Requesters should 
specify the preferred form or format (including electronic format) for 
the response. CEQ will accommodate such requests, if the record is 
readily reproducible in that form or format. Please be aware that FOIA 
requests and responses may themselves be made available for public 
inspection.
    (3) The CEQ FOIA Officer is responsible for acting on all initial 
requests; however, he or she may consult and refer, pursuant to Section 
552(a)(6)(B)(iii)(III) of the FOIA, with another agency if he or she 
determines that that agency is better able to act on the request. 
Whenever the CEQ FOIA Officer refers all or any part of the 
responsibility for responding to a request to another agency, he or she

[[Page 681]]

will notify the requester of the referral, the name of the agency and 
agency official to whom it has been referred, and which portion of the 
request has been referred. Unless a request is deemed ``expedited'' as 
set forth in Section 1515.7 below, the CEQ FOIA Officer will respond to 
requests in order of receipt. CEQ may use two or more processing tracks 
by distinguishing between simple and more complex requests based on the 
amount of time and work needed to process the request. CEQ may provide 
requesters on a slower track an opportunity to limit the scope of their 
request in order to qualify for faster processing.
    (4) The Council will make a reasonable effort to assist with 
defining the request to eliminate extraneous and unwanted materials and 
to keep search and copying fees to a minimum. If budgetary constraints 
exist, the requester should indicate the maximum fee he or she is 
prepared to pay to acquire the information. (See also Sec.  1515.11)
    (5) The Freedom of Information Act does not require a government 
agency to create or research information; rather, it only requires that 
existing records be made available to the public.



Sec.  1515.6  CEQ's response to a request.

    (a) Upon receipt of any written request for information or records, 
under the Act, the CEQ FOIA Officer or his or her designee, will make an 
initial determination on the request within 20 days (excepting 
Saturdays, Sundays and Federal holidays) from the date CEQ receives the 
request unless unusual or exceptional circumstances exist. The CEQ FOIA 
Officer will provide written notification of the determination, 
including, if applicable, notification that the request has been 
referred to another agency for consultation as set forth above in Sec.  
1515.5(b)(3). CEQ may make one request to the requester for information 
and toll the 20-day period while it is awaiting such information that it 
has reasonably requested from the requester. It may also toll the 20-day 
period if necessary to clarify with the requester issues regarding fee 
assessment. In either case, CEQ's receipt of the requester's response to 
its request for information or clarification ends the tolling period.
    (b) Requests received by the CEQ FOIA Officer or his or her designee 
will be assigned an individualized tracking number if they will take 
more than 10 days to process. Requesters may call the FOIA Public 
Liaison at (202) 456-6224 and, using the tracking number, obtain 
information about the request, including the date on which CEQ 
originally received the request and an estimated date on which CEQ will 
complete action on the request.
    (c) If it is appropriate to grant the request, a staff member will 
immediately collect the requested materials in order to accompany, 
wherever possible, the Freedom of Information Officer's letter conveying 
decision.
    (d) If a request is denied in part or in full, the letter conveying 
the decision will be signed by the CEQ FOIA Officer, and will include: 
The reasons for any denial, including any FOIA exemption(s) applied by 
the FOIA Officer in denying the request; an estimate of the volume of 
records or information withheld, in number of pages or in some other 
reasonable form of estimation. This estimate does not need to be 
provided, if the volume is otherwise indicated through exemptions on 
records disclosed in part or, if providing an estimate would harm an 
interest protected by an applicable exemption; and the procedure for 
filing an appeal.



Sec.  1515.7  Expedited processing.

    (a) Requests and appeals will be taken out of order and given 
expedited treatment whenever it is determined that they involve:
    (1) Circumstances in which the lack of expedited treatment could 
reasonably be expected to pose an imminent threat to the life or 
physical safety of an individual; or
    (2) An urgency to inform the public about an actual or alleged 
Federal Government activity, if made by a person primarily engaged in 
disseminating information.
    (b) A request for expedited processing may be made at the time of 
the initial request for records or at any later time.
    (c) A requester who seeks expedited processing must submit a written

[[Page 682]]

statement, certified to be true and correct to the best of that person's 
knowledge and belief, explaining in detail the basis for requesting 
expedited processing. For example, a requester within the category 
described in paragraph (a)(2) of this section, if not a full-time member 
of the news media, must establish that he or she is a person whose main 
professional activity or occupation is information dissemination, though 
it need not be his or her sole occupation. A requester within the 
category (a)(2) of this section must also establish a particular urgency 
to inform the public about the government activity involved in the 
request, beyond the public's right to know about government activity 
generally. Formal certification may be waived as a matter of 
administrative discretion.
    (d) Within 10 days of its receipt of a request for expedited 
processing, the CEQ FOIA Officer will decide whether to grant it and 
will notify the requester of the decision. If a request for expedited 
treatment is granted, the request will be placed in the expedited 
processing track, given priority, and processed as soon as practicable. 
If a request for expedited processing is denied, any appeal of that 
decision will be acted on expeditiously.



Sec.  1515.8  Appeals.

    (a) The requester may appeal an adverse determination, in any 
respect, to the CEQ FOIA Appeals Officer. Any appeal must be received by 
CEQ within 60 days of the date on the CEQ letter denying the request.
    (b) Appeals must be in writing and may be sent via e-mail to: 
[email protected]. They may also be sent via facsimile to: (202) 456-
0753 or via U.S. mail addressed to: FOIA Appeals Officer, Council on 
Environmental Quality, Executive Office of the President, 722 Jackson 
Place NW., Washington, DC 20503.
    (c) The appeal letter should specify the records requested and ask 
the Appeals Officer to review the determination made by the Freedom of 
Information Officer. The letter should explain the basis for the appeal.
    (d) The Appeals Officer will make a final determination on an appeal 
within 20 working days (excepting Saturdays, Sundays and Federal 
holidays) from the date CEQ receives the appeal. The Appeals Officer (or 
designee) will send a letter to the requester conveying the decision as 
soon as it is made. If an appeal is denied, in part or in whole, the 
letter will also include the provisions for judicial review.



Sec.  1515.9  Extending CEQ's time to respond.

    (a) In unusual circumstances as defined in paragraph (c) of this 
section, the time limits for responding to a request (Sec. Sec.  
1515.6(a) and 1515.8(d)) may be extended by the Council for not more 
than 10 working days. Extensions may be granted by the CEQ FOIA Officer 
in the case of initial requests and by the Appeals Officer in the case 
of any appeals. The extension period may be split between the initial 
request and the appeal but may not exceed 10 working days overall. 
Extensions will be confirmed in writing and set forth the reasons for 
the extension and the date that the final determination is expected.
    (b) With respect to a request for which a written notice under this 
section extends the time limits prescribed under Sec.  1515.6(a), the 
CEQ FOIA Officer will notify the requester, if the request cannot be 
processed within the time limit specified in Sec.  1515.6(a) and provide 
an opportunity to limit the scope of the request, so that it may be 
processed within that time limit or an opportunity to arrange an 
alternative time frame for processing the request or a modified request. 
A requester's refusal to reasonably modify the request or arrange such 
an alternative time frame will be considered as a factor in determining 
whether exceptional circumstances exist for purposes of 5 U.S.C. 
552(a)(6)(C). When CEQ reasonably believes that a requester, or a group 
of requesters, has submitted a request constituting a single request 
that would otherwise satisfy the unusual circumstances specified under 
this section, CEQ may aggregate those requests for purposes of this 
paragraph. Multiple requests involving unrelated matters will not be 
aggregated.
    (c) The term ``unusual circumstances'' means:

[[Page 683]]

    (1) The need to search for and collect the requested records from 
establishments that are separate from the office processing the request;
    (2) The need to search for, collect, and appropriately examine a 
voluminous amount of separate and distinct records which are demanded in 
a single request; or
    (3) The need for consultation, which will be conducted with all 
practicable speed, with another agency having a substantial interest in 
the determination of the request or among two or more components of the 
agency having substantial subject-matter interest therein.

                       Availability of Information



Sec.  1515.10  Obtaining available information.

    (a) When a request for information has been granted in whole or in 
part, CEQ will notify the requester in writing, inform the requester in 
the notice of any fee charged under Sec.  1515.11 and will disclose 
records to the requester promptly on payment of any applicable fees. The 
requested material may be made available on CEQ's Online FOIA Center, 
http://www.whitehouse.gov /administration/eop/ceq/foia, and also in the 
form or format requested if the record is readily reproducible in that 
form or format with reasonable effort. When a form or format of the 
response is not requested, CEQ will respond in the form or format in 
which the document is most accessible to CEQ. ``Readily reproducible'' 
means, with respect to electronic format, that the requested record or 
records can be downloaded or transferred intact to a computer disk or 
other electronic medium using equipment currently in use by CEQ.
    (b) Records disclosed in part will be marked or annotated to show 
information deleted, unless doing so would harm an interest protected by 
an applicable exemption. The location of the information deleted will 
also be indicated in the record, if technically feasible.
    (c) The legislative history of the establishment of CEQ states that 
the Congress intended CEQ to be a confidential advisor to the President 
on matters of environmental policy. Therefore, members of the public 
should be aware that communications between CEQ and the President 
(including communications between their staff) may be confidential; they 
will usually fall, at a minimum, within Exemption 5 of the Act. The 
Freedom of Information Officer shall review each request to determine 
whether the record is exclusively factual or may have factual portions 
which may be reasonably segregated and made available to the requester. 
Furthermore, on the recommendation of the CEQ FOIA Officer or Appeals 
Officer, CEQ will consider the release of an entire record, even if it 
comes within an exemption or contains policy advice, if its disclosure 
would not impair Executive policymaking processes or CEQ's participation 
in decisionmaking.

                                  Costs



Sec.  1515.11  Definitions.

    For purposes of these regulations:
    Commercial use request means a request from or on behalf of a person 
who seeks information for a use or purpose that furthers the requester's 
or other person's commercial, trade, or profit interests.
    Direct costs means those costs incurred in searching for and 
duplicating (and, in the case of commercial use requests, reviewing) 
documents to respond to a FOIA request. Direct costs include, for 
example, salaries of employees who perform the work and costs of 
conducting large-scale computer searches.
    Duplicate means to copy records to be released to the FOIA 
requester. Copies can take the form of paper, audio-visual materials, or 
electronic records, among others.
    Educational institution means a school that operates a program of 
scholarly research.
    Non-commercial scientific institution means an institution that is 
not operated on a commercial basis and that operates solely for the 
purpose of conducting scientific research the results of which are not 
intended to promote any particular product or industry.
    Representative of the news media means any person or entity that 
gathers information of potential interest to

[[Page 684]]

a segment of the public, uses its editorial skills to turn the raw 
materials into a distinct work, and distributes that work to an 
audience.
    Review means to examine a record to determine whether any portion of 
the record may be withheld and to process a record for disclosure, 
including by redacting it.
    Search means to look for and retrieve records covered by a FOIA 
request, including by looking page-by-page or line-by-line to identify 
responsive material within individual records.



Sec.  1515.12  Fees in general.

    CEQ shall charge fees that recoup the full allowable direct costs it 
incurs in responding to FOIA requests. CEQ may assess charges for time 
spent searching for records even if CEQ fails to locate the records or 
if the records are located and determined to be exempt from disclosure. 
In general, CEQ shall apply the following fee schedule, subject to 
Sec. Sec.  1515.13 through 1515.15:
    (a) Manual searches. Time devoted to manual searches shall be 
charged on the basis of the salary of the employee(s) conducting the 
search (basic hourly rate(s) of pay for the employee(s), plus 16 
percent).
    (b) Electronic searches. Fees shall reflect the direct cost of 
conducting the search. This will include the cost of operating the 
central processing unit for that portion of operating time that is 
directly attributable to searching for and printing records responsive 
to the FOIA request and operator/programmer salary attributable to the 
search.
    (c) Record reviews. Time devoted to reviewing records shall be 
charged on the same basis as under paragraph (a) of this section, but 
shall only be applicable to the review of records located in response to 
commercial use requests.
    (d) Duplication. Fees for copying paper records or for printing 
electronic records shall be assessed at a rate of $.15 per page. For 
other types of copies such as disks or audio visual tapes, CEQ shall 
charge the direct cost of producing the document(s). If total costs are 
expected to exceed $25, the FOIA Officer shall provide the requester 
with an estimate in writing and, in return, obtain from the requester a 
commitment to pay the estimated fee. This does not apply if the 
requester has indicated in advance a willingness to pay fees as high as 
those anticipated. If a requester wishes to limit costs, the FOIA 
Officer shall provide the requester an opportunity to reformulate the 
request in order to reduce costs. If the requester reformulates a 
request, it shall be considered a new request and the 20-day period 
described in Sec.  1515.6(a) shall be deemed to begin when the FOIA 
Officer receives the request.
    (e)(1) Advance payments required. The FOIA Officer may require a 
requester to make an advance deposit of up to the amount of the entire 
anticipated fee before the FOIA Officer begins to process the request 
if:
    (i) The FOIA Officer estimates that the fee will exceed $250; or
    (ii) The requester has previously failed to pay a fee in a timely 
fashion.
    (2) When the FOIA Officer requires a requester to make an advance 
payment, the 20-day period described in Sec.  1515.6(a) shall begin when 
the FOIA Officer receives the payment.
    (f) No assessment of fee. CEQ shall not charge a fee to any 
requester if:
    (1) The cost of collecting the fee would be equal to or greater than 
the fee itself; or
    (2) After the effective date of these regulations CEQ fails to 
comply with a time limit under the Freedom of Information Act for 
responding to the request for records where no unusual or exceptional 
circumstances apply.



Sec.  1515.13  Fees for categories of requesters.

    CEQ shall assess fees for certain categories of requesters as 
follows:
    (a) Commercial use requesters. In responding to commercial use 
requests, CEQ shall assess fees that recover the full direct costs of 
searching for, reviewing, and duplicating records.
    (b) Educational and non-commercial scientific institutions. CEQ 
shall provide records to requesters in this category for the cost of 
duplication alone, excluding charges for the first 100 pages. To qualify 
for inclusion in this fee category, a requester must show that the 
request is authorized by and is made under the auspices of a qualifying 
institution and that the records are

[[Page 685]]

sought to further scholarly research, not an individual goal.
    (c) Representatives of the news media. CEQ shall provide records to 
requesters in this category for the cost of duplication alone, excluding 
charges for the first 100 pages.
    (d) All other requesters. CEQ shall charge requesters who do not 
fall within paragraphs (a) through (c) of this section fees that recover 
the full direct cost of searching for and duplicating records, excluding 
charges for the first 100 pages of reproduction and the first two hours 
of search time.



Sec.  1515.14  Other charges.

    CEQ may apply other charges, including the following:
    (a) Special charges. CEQ shall recover the full cost of providing 
special services, such as sending records by express mail, to the extent 
that CEQ elects to provide them in that manner.
    (b) Interest charges. CEQ may begin assessing interest charges on an 
unpaid bill starting on the 31st day following the day on which the FOIA 
Officer sent the billing. Interest shall be charged at the rate 
prescribed in 31 U.S.C. 3717 and will accrue from the date of billing.
    (c) Aggregating requests. When the FOIA Officer reasonably believes 
that a requester or a group of requesters acting in concert is 
attempting to divide a request into a series of requests for the purpose 
of avoiding fees, the FOIA Officer shall aggregate those requests and 
charge accordingly.



Sec.  1515.15  Payment and waiver.

    (a) Remittances. Payment shall be made in the form of check or money 
order made payable to the Treasury of the United States. At the time the 
FOIA Officer notifies a requester of the applicable fees, the Officer 
shall inform the requester of where to send the payment.
    (b) Waiver of fees. CEQ may waive all or part of any fee provided 
for in Sec. Sec.  1515.12 and 1515.13 when the FOIA Officer deems that 
disclosure of the information is in the general public's interest 
because it is likely to contribute significantly to public understanding 
of the operations or activities of the government and is not primarily 
in the commercial interest of the requester. In determining whether a 
fee should be waived, the FOIA Officer may consider whether:
    (1) The subject matter specifically concerns identifiable operations 
or activities of the government;
    (2) The information is already in the public domain;
    (3) Disclosure of the information would contribute to the 
understanding of the public-at-large as opposed to a narrow segment of 
the population;
    (4) Disclosure of the information would significantly enhance the 
public's understanding of the subject matter;
    (5) Disclosure of the information would further a commercial 
interest of the requester; and
    (6) The public's interest is greater than any commercial interest of 
the requester.



Sec.  1515.16  Other rights and services.

    Nothing in this subpart will be construed to entitle any person, as 
of right, to any service or to the disclosure of any record to which 
such person is not entitled under the FOIA.



Sec. Sec.  1515.17-1515.19  [Reserved]



PART 1516_PRIVACY ACT IMPLEMENTATION--Table of Contents



Sec.
1516.1 Purpose and scope.
1516.2 Definitions.
1516.3 Procedures for requests pertaining to individual records in a 
          record system.
1516.4 Times, places, and requirements for the identification of the 
          individual making a request.
1516.5 Disclosure of requested information to the individual.
1516.6 Request for correction or amendment to the record.
1516.7 Agency review of request for correction or amendment of the 
          record.
1516.8 Appeal of an initial adverse agency determination on correction 
          or amendment of the record.
1516.9 Disclosure of a record to a person other than the individual to 
          whom the record pertains.
1516.10 Fees.

    Authority: 5 U.S.C. 552a; Pub. L. 93-579.

    Source: 42 FR 32537, June 27, 1977, unless otherwise noted.

[[Page 686]]



Sec.  1516.1  Purpose and scope.

    The purposes of these regulations are to:
    (a) Establish a procedure by which an individual can determine if 
the Council on Environmental Quality (hereafter known as the Council) 
maintains a system of records which includes a record pertaining to the 
individual; and
    (b) Establish a procedure by which an individual can gain access to 
a record pertaining to him or her for the purpose of review, amendment 
and/or correction.



Sec.  1516.2  Definitions.

    For the purpose of these regulations:
    (a) The term individual means a citizen of the United States or an 
alien lawfully admitted for permanent residence;
    (b) The term maintain means maintain, collect, use or disseminate;
    (c) The term record means any item or collection or grouping of 
information about an individual that is maintained by the Council 
(including, but not limited to, his or her employment history, payroll 
information, and financial transactions), and that contains his or her 
name, or an identifying number, symbol, or other identifying particular 
assigned to the individual such as a social security number;
    (d) The term system of records means a group of any records under 
the control of the Council from which information is retrieved by the 
name of the individual or by some identifying number, symbol, or other 
identifying particular assigned to the individual; and
    (e) The term routine use means with respect to the disclosure of a 
record, the use of such record for a purpose which is compatible with 
the purpose for which it was collected.



Sec.  1516.3  Procedures for requests pertaining to individual
records in a record system.

    An individual shall submit a written request to the Administrative 
Officer of the Council to determine if a system of records named by the 
individual contains a record pertaining to the individual. The 
individual shall submit a written request to the Administrative Officer 
of the Council which states the individual's desire to review his or her 
record. The Administrative Officer of the Council is available to answer 
questions regarding these regulations and to provide assistance in 
locating records in the Council's system of records.

[42 FR 32537, June 27, 1977; 42 FR 35960, July 13, 1977]



Sec.  1516.4  Times, places, and requirements for the identification 
of the individual making a request.

    An individual making a request to the Administrative Officer of the 
Council pursuant to Sec.  1516.3 shall present the request at the 
Council's office, 722 Jackson Place NW., Washington, DC 20006, on any 
business day between the hours of 9 a.m. and 5 p.m. and should be 
prepared to identify himself by signature. Requests will also be 
accepted in writing if mailed to the Council's offices and signed by the 
requester.



Sec.  1516.5  Disclosure of requested information to the individual.

    Upon verification of identity, the Council shall disclose to the 
individual the information contained in the record which pertains to 
that individual.
    (a) The individual may be accompanied for this purpose by a person 
of his choosing.
    (b) Upon request of the individual to whom the record pertains, all 
information in the accounting of disclosures will be made available.

[42 FR 35960, July 13, 1977]



Sec.  1516.6  Request for correction or amendment to the record.

    The individual may submit a request to the Administrative Officer of 
the Council which states the individual's desire to correct or to amend 
his or her record. This request must be made in accordance with the 
procedures of Sec.  1516.4 and shall describe in detail the change which 
is requested.

[42 FR 32537, June 27, 1977. Redesignated at 42 FR 35960, July 13, 1977]



Sec.  1516.7  Agency review of request for correction or amendment of the record.

    Within ten working days of the receipt of a request to correct or to

[[Page 687]]

amend a record, the Administrative Officer of the Council will 
acknowledge in writing such receipt and promptly either:
    (a) Make any correction or amendment of any portion thereof which 
the individual believes is not accurate, relevant, timely, or complete; 
or
    (b) Inform the individual of his or her refusal to correct or amend 
the record in accordance with the request, the reason for the refusal, 
and the procedure established by the Council for the individual to 
request a review of that refusal.



Sec.  1516.8  Appeal of an initial adverse agency determination on
correction or amendment of the record.

    An individual may appeal refusal by the Administrative Officer of 
the Council to correct or to amend his or her record by submitting a 
request for a review of such refusal to the General Counsel, Council on 
Environmental Quality, 722 Jackson Place NW., Washington, DC 20006. The 
General Counsel shall, not later than thirty working days from the date 
on which the individual requests such a review, complete such review and 
make a final determination unless, for good cause shown, the General 
Counsel extends such thirty day period. If, after his or her review, the 
General Counsel also refuses to correct or to amend the record in 
accordance with the request, the individual may file with the Council a 
concise statement setting forth the reasons for his or her disagreement 
with the General Counsel's decision and may seek judicial relief under 5 
U.S.C. 552a(g)(1)(A).



Sec.  1516.9  Disclosure of a record to a person other than the
individual to whom the record pertains.

    The Council will not disclose a record to any individual other than 
to the individual to whom the record pertains without receiving the 
prior written consent of the individual to whom the record pertains, 
unless the disclosure either has been listed as a ``routine use'' in the 
Council's notices of its systems of records or falls within the special 
conditions of disclosure set forth in section 3 of the Privacy Act of 
1974.



Sec.  1516.10  Fees.

    If an individual requests copies of his or her record, he or she 
shall be charged ten cents per page, excluding the cost of any search 
for the record, in advance of receipt of the pages.



PART 1517_PUBLIC MEETING PROCEDURES OF THE COUNCIL ON ENVIRONMENTAL
QUALITY--Table of Contents



Sec.
1517.1 Policy and scope.
1517.2 Definitions.
1517.3 Open meeting requirement.
1517.4 Exceptions.
1517.5 Procedure for closing meetings.
1517.6 Notice of meetings.
1517.7 Records of closed meetings.

    Authority: 5 U.S.C. 552b(g); Pub. L. 94-409.

    Source: 42 FR 20818, Apr. 22, 1977, unless otherwise noted.



Sec.  1517.1  Policy and scope.

    Consistent with the policy that the public is entitled to the 
fullest information regarding the decisionmaking processes of the 
Federal Government, it is the purpose of this part to open the meetings 
of the Council on Environmental Quality to public observation while 
protecting the rights of individuals and the ability of the Council to 
carry out its primary responsibility of providing advice to the 
President. Actions taken by the Chairman acting as Director of the 
Office of Environmental Quality and Council actions involving advice to 
the President when such advice is not formulated collegially during a 
meeting are outside the scope of this part. In addition to conducting 
the meetings required by this part, it is the Council's policy to 
conduct, open to public observation, periodic meetings involving Council 
discussions of Council business, including where appropriate, matters 
outside the scope of this part. This part does not affect the procedures 
set forth in part 1515 pursuant to which records of the Council are made 
available to the public for inspection and copying, except that the 
exemptions set forth in Sec.  1517.4(a) shall govern in the case of any 
request made to copy or inspect

[[Page 688]]

the transcripts, recording or minutes described in Sec.  1517.7.

[47 FR 6277, Feb. 11, 1982]



Sec.  1517.2  Definitions.

    For the purpose of this part:
    (a) The term Council shall mean the Council on Environmental Quality 
established under title II of the National Environmental Policy Act of 
1969 (42 U.S.C. 4321 through 4347).
    (b) The term meeting means the deliberations of at least two Council 
members where such deliberations determine or result in the joint 
conduct or disposition of official collegial Council business, but does 
not include deliberations to take actions to open or close a meeting 
under Sec. Sec.  1517.4 and 1517.5 or to release or withhold information 
under Sec. Sec.  1517.4 and 1517.7. ``Meeting'' shall not be construed 
to prevent Council members from considering individually Council 
business that is circulated to them sequentially in writing.
    (c) Director means the Chairman of the Council on Environmental 
Quality acting as the head of the Office of Environmental Quality 
pursuant to the Environmental Quality Improvement Act of 1970, Pub. L. 
91-224, 42 U.S.C. 4371 through 4374.

[44 FR 34946, June 18, 1979, as amended at 47 FR 6277, Feb. 11, 1982]



Sec.  1517.3  Open meeting requirement.

    (a) Every portion of every meeting of the Council is open to public 
observation subject to the exemptions provided in Sec.  1517.4. Members 
of the Council may not jointly conduct or dispose of the business of the 
Council other than in accordance with this part.
    (b) The Council will conduct open to public observation periodic 
meetings involving Council discussions of Council business including 
where appropriate matters outside the scope of this part. Such meetings 
will be noticed pursuant to Sec.  1517.6.
    (c) Members of the public may attend open meetings of the Council 
for the sole purpose of observation and may not participate in or 
photograph any meeting without prior permission of the Council. Members 
of the public who desire to participate in or photograph an open meeting 
of the Council may request permission to do so from the General Counsel 
of the Council before such meeting. Members of the public may record 
open meetings of the Council by means of any mechanical or electronic 
device unless the Council determines such recording would disrupt the 
orderly conduct of such meeting.

[44 FR 34946, June 18, 1979, as amended at 47 FR 6277, Feb. 11, 1982]



Sec.  1517.4  Exceptions.

    (a) A meeting or portion thereof may be closed to public 
observation, and information pertaining to such meeting or portion 
thereof may be withheld from the public, if the Council determines that 
such meeting or portion thereof or disclosure of such information is 
likely to:
    (1) Disclose matters that are (i) specifically authorized under 
criteria established by an Executive order to be kept secret in the 
interest of national defense or foreign policy and (ii) in fact properly 
classified pursuant to that Executive order;
    (2) Relate solely to the internal personnel rules and practices of 
the Council;
    (3) Disclose matters specifically exempted from disclosure by 
statute (other than the Freedom of Information Act, 5 U.S.C. 552), 
provided that the statute: (i) Requires that the matters be withheld 
from the public in such a manner as to leave no discretion on the issue, 
or (ii) establishes particular criteria for withholding or refers to 
particular types of matters to be withheld;
    (4) Disclose the trade secrets and commercial or financial 
information obtained from a person and privileged or confidential;
    (5) Involve accusing any person of a crime, or formally censuring 
any person;
    (6) Disclose information of a personal nature if disclosure would 
constitute a clearly unwarranted invasion of personal privacy;
    (7) Disclose investigatory records compiled for law enforcement 
purposes, or information which if written would be contained in such 
records, but only to the extent that the production of those records or 
information would:

[[Page 689]]

    (i) Interfere with enforcement proceedings,
    (ii) Deprive a person of a right to a fair trial or an impartial 
adjudication,
    (iii) Constitute an unwarranted invasion of personal privacy,
    (iv) Disclose the identity of a confidential source and, in the case 
of a record compiled by a criminal law enforcement authority in the 
course of a criminal investigation, or by an agency conducting a lawful 
national security intelligence investigation, confidential information 
furnished only by the confidential source,
    (v) Disclose investigative techniques and procedures, or,
    (vi) Endanger the life or physical safety of law enforcement 
personnel;
    (8) Disclose information contained in or related to examination, 
operating, or condition reports prepared by, on behalf of, or for the 
use of an agency responsible for the regulation or supervision of 
financial institutions;
    (9) Disclose information the premature disclosure of which would be 
likely to significantly frustrate implementation of a proposed action of 
the Council. This exception shall not apply in any instance where the 
Council has already disclosed to the public the content or nature of the 
proposed action, or where the Council is required by law to make such 
disclosure on its own initiative prior to taking final action on the 
proposal; or
    (10) Specifically concern the issuance of a subpoena by the Council, 
or the participation of the Council in a civil action or proceeding, an 
action in a foreign court or international tribunal, or an arbitration, 
or the initiation, conduct, or disposition by the Council of a 
particular case of formal adjudication pursuant to the procedures in 5 
U.S.C. 554 or otherwise involving a determination on the record after 
opportunity for a hearing.
    (b) Before a meeting is closed to public observation the Council 
shall determine whether or not the public interest requires that the 
meeting be open. The Council may open a meeting to public observation 
which could be closed under paragraph (a) of this section, if the 
Council finds it to be in the public interest to do so.



Sec.  1517.5  Procedure for closing meetings.

    (a) A majority of the entire membership of the Council may vote to 
close to public observation a meeting or a portion or portions thereof, 
or to withhold information pertaining to such meeting. A separate vote 
of the members of the Council shall be taken with respect to each 
meeting of the Council, a portion or portions of which are proposed to 
be closed to the observation of the public or with respect to any 
information concerning such meetings or portion thereof. A single vote 
may be taken with respect to a series of meetings, a portion or portions 
of which are proposed to be closed to the public, or with respect to 
information concerning such series of meetings, so long as each meeting 
in such series involves the same particular matters and is scheduled to 
be held no more than thirty days after the initial meeting in such 
series. The vote of each member of the Council participating in a vote 
shall be recorded and no proxies shall be allowed.
    (b) Whenever any person whose interest may be directly affected by a 
portion of a meeting requests that the Council close that portion to 
public observation for any of the reasons referred to in Sec.  1517.4(a) 
the Council, upon request of any of the members of the Council, shall 
decide by recorded vote whether to close that portion of the meeting.
    (c) For every meeting or portion thereof closed under this part, the 
General Counsel of the Council before such meeting is closed shall 
publicly certify that, in his or her opinion, the meeting may properly 
be closed to the public stating each relevant exemptive provision. The 
Council shall retain a copy of the General Counsel's certification, 
together with a statement from the presiding officer of the meeting 
setting forth the time and place of the meeting and listing the persons 
present.
    (d) Within one day of any vote taken on a proposal to close a 
meeting, the Council shall make publicly available a record reflecting 
the vote of each member on the question. In addition, within one day of 
any vote which closes a portion or portions of a meeting to the public, 
the Council shall make publicly

[[Page 690]]

available a full written explanation of its closure action together with 
a list naming all persons expected to attend and identifying their 
affiliation, unless such disclosure would reveal the information that 
the meeting itself was closed to protect.
    (e) Following any announcement that the Council intends to close a 
meeting or portion thereof, any person may make a request that the 
meeting or portion thereof be opened. Such request shall be made of the 
Chairman of the Council who shall ensure that the request is circulated 
to all members of the Council on the same business day on which it is 
received. The request shall set forth the reasons why the requestor 
believes the meeting should be open. The Council upon the request of any 
member or its General Counsel, shall vote on the request.



Sec.  1517.6  Notice of meetings.

    (a) Except as otherwise provided in this section, the Council shall 
make a public announcement at least one week before a meeting, to 
include the following:
    (1) Time, place, and subject matter of the meeting;
    (2) Whether the meeting is to be open or closed; and
    (3) Name and telephone number of the official who will respond to 
requests for information about the meeting.
    (b) A majority of the members of the Council may determine by 
recorded vote that the business of the Council requires a meeting to be 
called with less than one week's notice. At the earliest practicable 
time, the Council shall publicly announce the time, place and subject 
matter of the meeting, and whether or not it is to be open or closed to 
the public.
    (c) If announcement of the subject matter of a closed meeting would 
reveal the information that the meeting itself was closed to protect, 
the subject matter shall not be announced.
    (d) Following the public announcement required by paragraph (a) or 
(b) of this section:
    (1) A majority of the members of the Council may change the time or 
place of a meeting. At the earliest practicable time, the Council shall 
publicly announce the change.
    (2) A majority of the entire membership of the Council may change 
the subject matter of a meeting, or the determination to open or close a 
meeting to the public, if it determines by a recorded vote that the 
change is required by the business of the Council and that no earlier 
announcement of the change was possible. At the earliest practicable 
time, the Council shall publicly announce the change, and the vote of 
each member upon the change.
    (e) Individuals or organizations having a special interest in 
activities of the Council may request the Council to place them on a 
mailing list for receipt of information available under this section.
    (f) Following public announcement of a meeting, the time or place of 
a meeting may be changed only if the change is announced publicly at the 
earliest practicable time. The subject matter of a meeting or the 
determination to open or close a meeting may be changed following public 
announcement of a meeting only if both of the following conditions are 
met:
    (1) There must be a recorded vote of a majority of the Council that 
the business of the Council requires the change and that no earlier 
announcement of such change was possible; and
    (2) There must be a public announcement of the change and of the 
individual Council members' votes at the earliest practicable time.
    (g) Immediately following each public announcement required by this 
section, the following information, as applicable, shall be submitted 
for publication in the Federal Register.
    (1) Notice of the time, place, and subject matter of a meeting;
    (2) Whether the meeting is open or closed;
    (3) Any change in one of the preceding; and
    (4) The name and telephone number of the official who will respond 
to requests for information about the meeting.



Sec.  1517.7  Records of closed meetings.

    (a) A record of each meeting or portion thereof which is closed to 
the public shall be made and retained for two

[[Page 691]]

years or for one year after the conclusion of any Council proceeding 
involved in the meeting whichever occurs later. The record of any 
portion of a meeting closed to the public shall be a verbatim transcript 
or electronic recording. In lieu of a transcript or recording, a 
comprehensive set of minutes may be produced if the closure decision was 
made pursuant to Sec.  1517.4(a) (8) or (10).
    (b) If minutes are produced, such minutes shall fully and clearly 
describe all matters discussed, provide a full and accurate summary of 
any actions taken and the reasons expressed therefor, and include a 
description of each of the views expressed on any item. The minutes 
shall also reflect the vote of each member of the Council on any roll 
call vote taken during the proceedings and identify all documents 
produced at the meeting.
    (c) The following documents shall be retained by the Council as part 
of the transcript, recording, or minutes of the meeting:
    (1) Certification by the General Counsel that the meeting may 
properly be closed; and
    (2) Statement from the presiding officer of the meeting setting 
forth the date, time, and place of the meeting and listing the persons 
present.
    (d) The Council shall make promptly available to the public at its 
offices at 722 Jackson Place, NW., Washington, DC the transcript, 
electronic recording, or minutes maintained as a record of a closed 
meeting, except for such information as may be withheld under one of the 
provisions of Sec.  1517.5. Copies of such transcript, minutes, or 
transcription of an electronic recording, disclosing the identity of 
each speaker, shall be furnished to any person at the actual cost of 
duplication or transcription.
    (e) [Reserved]
    (f) Requests to review or obtain copies of records other than 
transcripts, electronic recordings or minutes of a meeting will be 
processed under the Freedom of Information Act (5 U.S.C. 552) or, where 
applicable, the Privacy Act of 1974. (5 U.S.C. 552a). Nothing in these 
regulations authorizes the Council to withhold from any individual any 
record, including the transcripts or electronic recordings described in 
Sec.  1517.8, to which the individual may have access under the Privacy 
Act of 1974 (5 U.S.C. 552a).



PART 1518_OFFICE OF ENVIRONMENTAL QUALITY MANAGEMENT FUND--Table of Contents



Sec.
1518.1 Purpose.
1518.2 Definitions.
1518.3 Policy.
1518.4 Procedures.

    Authority: 42 U.S.C. 4375(c).

    Source: 67 FR 62189, Oct. 4, 2002, unless otherwise noted.



Sec.  1518.1  Purpose.

    The purpose of the OEQ Management Fund is to finance:
    (a) Study contracts that are jointly sponsored by OEQ and one or 
more other Federal agency; and
    (b) Federal interagency environmental projects (including task 
forces) in which OEQ participates. See 42 U.S.C. 4375(a).



Sec.  1518.2  Definitions.

    (a) Advance Payment: Amount of money prepaid pursuant to statutory 
authorization in contemplation of the later receipt of goods, services, 
or other assets.
    (b) Director: The Director of the Office of Environmental Quality. 
The Environmental Quality Improvement Act specifies that the Chairman of 
the Council on Environmental quality shall serve as the Director of OEQ. 
42 U.S.C. 4372(a).
    (c) OEQ Management Fund (``Fund''): The Management Fund for the 
Office of Environmental Quality.
    (d) Interagency Agreement: A document jointly executed by OEQ and 
another agency or agencies, which sets forth the details of a joint 
study or project and the funding arrangements for such a study or 
project.
    (e) Project Officer: The Council on Environmental Quality staff 
member charged with day-to-day supervision of an OEQ Management Fund 
study or project.
    (f) Source: The agency or account from which funds are contributed 
into the Fund.

[[Page 692]]



Sec.  1518.3  Policy.

    (a) All studies and projects financed through the OEQ Management 
Fund shall be consistent with the purposes and goals of the National 
Environmental Policy Act and/or the Environmental Quality Improvement 
Act.
    (b) Agency funds accepted by the Director for transfer into the OEQ 
Management Fund shall specify the purposes permissible under the source 
appropriation and any restrictions relating thereto.
    (c) The Director may authorize expenditures to support OEQ 
Management Fund studies and projects, including:
    (1) Leasing office space and providing utilities;
    (2) Leasing or purchasing equipment;
    (3) Funding travel;
    (4) Contracting for goods and services; and
    (5) Funding consultants and personnel costs for task force 
employees.
    (d) In carrying out the purposes of the OEQ Management Fund, the 
Director is authorized to contract with public or private agencies, 
institutions, organizations and individuals, by negotiation, without 
regard to 31 U.S.C. 3324(a) and (b) 41 U.S.C. 5, and 42 U.S.C. 4372(e). 
All such contracting activities shall be accomplished through the Office 
of Administration, Executive Office of the President. The Director may, 
by interagency agreement with another federal agency or agencies and 
with the concurrence of the Office of Administration's Financial 
Management Division, obtain specific administrative services (including 
contracting activities) in support of OEQ Management Fund studies or 
projects.
    (e) Task forces and projects funded by the OEQ Management Fund are 
permitted to make expenditures for all project and study activities, 
except for compensation or benefits for full-time OEQ employees or to 
reimburse OEQ or CEQ for ordinarily appropriated expenses, such as 
salaries, benefits, rent, telephone and supplies.



Sec.  1518.4  Procedures.

    (a) Charters: (1) A charter must be prepared for each project or 
study to be financed and supported by the OEQ Management Fund.
    (2) The charter must clearly state the relation of the study or 
project to the goals and purposes of the Office of Environmental Quality 
and the National Environmental Policy Act; describe the study or 
project; identify the participating agency or agencies; provide the 
names, titles and phone numbers of the Project Officer and 
administrative contact.
    (3) Charters may be amended by preparing a formal amendment, which 
sets forth the new language to be incorporated in the existing charter.
    (4) The Director shall approve all Management Fund charters and 
amendments in writing.
    (5) Copies of each charter and charter amendment approved by the 
Director shall be provided to the Contracts Branch and the Financial 
Management Division of the Office of Administration, Executive Office of 
the President.
    (b) Finances and accounting: (1) Annual budget estimates shall be 
prepared for the OEQ Management Fund.
    (2) An operating budget for each project or study shall be submitted 
to the Financial Management Division of the Office of Administration, 
Executive Office of the President.
    (3) All contributions from other agencies to the OEQ Management Fund 
for a joint study or project shall be accomplished by interagency 
agreements, which shall provide for full payment of funds on an advance 
basis. 42 U.S.C. 4375(a).
    (4) All contributions by the Office of Environmental Quality or the 
Council on Environmental Quality to the OEQ Management Fund for a joint 
study or project shall be accomplished by a letter of transmittal which 
specifies the particular study or project to be funded. A copy of this 
transmittal letter shall be provided to the Financial Management 
Division of the Office of Administration, Executive Office of the 
President.
    (5) The OEQ Management Fund is a no-year appropriations account, 
which can accept one-year or multiple-year funds, and is available until 
the objectives for which the authority was made available are attained. 
Funds transferred into the Management Fund are individually accounted 
for and expire under the terms of their appropriation.

[[Page 693]]

    (6) Any agency, including the Office of Environmental Quality and 
the Council on Environmental Quality, may provide technical expertise, 
physical resources, facilities, equipment, or other assets; perform 
support or administrative services; or assign detailees or agency 
representatives to an OEQ Management Fund project or study. These 
contributions may be in addition to funding.
    (7) Subaccounts shall be established within OEQ Management Fund for 
each project or study. All expenditures for a particular project or 
study must be matched with the source contribution and approved by the 
Director or the Project Officer.
    (8) The Director may transfer Management Fund resources for any 
study or project to other federal accounts or other OEQ subaccounts 
provided that the transfer:
    (i) Is approved in writing by the source agency that provided the 
portion of the funds being transferred;
    (ii) Promotes the statutory mission of OEQ; and
    (iii) Is justified by the Director as being in the best interests of 
the government.
    (9) Financial transactions shall be classified under each Management 
Funds subaccount in sufficient detail to satisfy management planning, 
control requirements and financial audit requirements.
    (10) All fund expenditures must comport with the purposes of the 
Management Fund and follow CEQ approval procedures. Any fund 
expenditures pursuant to interagency agreement for the provision of 
administrative services shall comport with the CEQ approval procedures 
specified in the interagency agreement.

                       PARTS 1519	1599 [RESERVED]

[[Page 695]]



       CHAPTER VI--CHEMICAL SAFETY AND HAZARD INVESTIGATION BOARD




  --------------------------------------------------------------------
Part                                                                Page
1600            Organization and functions of the Chemical 
                    Safety and Hazard Investigation Board...         697
1601            Procedures for disclosure of records under 
                    the Freedom of Information Act..........         699
1602            Protection of privacy and access to 
                    individual records under the Privacy Act 
                    of 1974.................................         714
1603            Rules implementing the Government in the 
                    Sunshine Act............................         718
1604            Reporting of accidental releases............         723
1610            Administrative investigations...............         725
1611            Testimony by employees in legal proceedings.         727
1612            Production of records in legal proceedings..         730
1613-1619

 [Reserved]

1620            Administrative claims arising under the 
                    Federal Tort Claims Act.................         732
1621-1699

 [Reserved]

[[Page 697]]



PART 1600_ORGANIZATION AND FUNCTIONS OF THE CHEMICAL 
SAFETY AND HAZARD INVESTIGATION BOARD--Table of Contents



Sec.
1600.1 Purpose.
1600.2 Organization.
1600.3 Functions.
1600.4 Operation.
1600.5 Quorum and voting requirements.
1600.6 Office location.

    Authority: 5 U.S.C. 301, 552(a)(1); 42 U.S.C. 7412(r)(6)(N).

    Source: 68 FR 65403, Nov. 20, 2003, unless otherwise noted.



Sec.  1600.1  Purpose.

    This part describes the organization, functions, and operation of 
the Chemical Safety and Hazard Investigation Board (CSB). The CSB is an 
independent agency of the United States created by the Clean Air Act 
Amendments of 1990 [Pub. L. 101-549, 104 Stat. 2399, codified at 42 
U.S.C. 7412(r)(6) et seq.]. Information about the CSB is available from 
its Web site, http://www.csb.gov.



Sec.  1600.2  Organization.

    (a) The CSB's Board consists of five Members appointed by the 
President with the advice and consent of the Senate. The President 
designates one of the Members as Chairperson with the advice and consent 
of the Senate. The Members exercise various functions, powers, and 
duties set forth in the Clean Air Act Amendments of 1990 (42 U.S.C. 
7412(r)(6) et seq.).
    (b) The CSB's staff is comprised of the following administrative 
units and such other units as established by the CSB Board:
    (1) The Office of Administration;
    (2) The Office of Investigations and Recommendations;
    (3) The Office of the General Counsel;
    (4) The Office of Financial Operations; and
    (5) The Office of Equal Employment Opportunity.

[68 FR 65403, Nov. 20, 2003, as amended at 88 FR 36256, June 2, 2023]



Sec.  1600.3  Functions.

    (a) The CSB investigates chemical accidents and hazards, 
recommending actions to protect workers, the public, and the 
environment. The CSB is responsible for the investigation and 
determination of the facts, conditions, and circumstances and the cause 
or probable cause or causes of any accidental release resulting in a 
fatality, serious injury, or substantial property damages.
    (b) The CSB makes safety recommendations to Federal, State, and 
local agencies, including the Environmental Protection Agency and the 
Occupational Safety and Health Administration and private organizations 
to reduce the likelihood of recurrences of chemical incidents. It 
initiates and conducts safety studies and special investigations on 
matters pertaining to chemical safety.
    (c) The CSB issues reports pursuant to its duties to determine the 
cause or probable cause or causes of chemical incidents and to report 
the facts, conditions, and circumstances relating to such incidents; and 
issues and makes available to the public safety recommendations, safety 
studies, and reports of special investigations.



Sec.  1600.4  Operation.

    In exercising its functions, duties, and responsibilities, the CSB 
utilizes:
    (a) The CSB's staff, consisting of specialized offices performing 
investigative, administrative, legal, and financial work for the Board.
    (b) Rules published in the Federal Register and codified in this 
title of the Code of Federal Regulations.
    (c) Meetings of the Board Members conducted pursuant to the 
Government in the Sunshine Act and part 1603 of this title (CSB Rules 
Implementing the Government in the Sunshine Act) or voting by notation 
as provided in Sec.  1600.5(b).
    (d) Public hearings in connection with incident or hazard 
investigations.
    (e) Board Orders and other policies and procedures adopted by the 
Board.

]68 FR 65403, Nov. 20, 2003, as amended at 88 FR 36256, June 2, 2023]

[[Page 698]]



Sec.  1600.5  Quorum and voting requirements.

    (a) Quorum requirements. A quorum of the Board for the transaction 
of business shall consist of three Members; provided, however, that if 
the number of Board Members in office is fewer than three, a quorum 
shall consist of the number of Members in Office, subject to the 
limitations on the authority of a single-Member Board set forth in this 
section and in Board Orders adopted by the Board; and provided further 
that on any matter of business as to which the number of Members in 
office, minus the number of Members who have disqualified themselves 
from consideration of such matter is two, two Members shall constitute a 
quorum for purposes of such matter. Once a quorum is constituted, a 
simple majority of voting Members is required to approve an item of the 
Board's business. A tie vote results in no action. If the Board consists 
of only a single Member (whether the Chairperson or another Member), 
that single Member may not transact Board business or take any action 
that requires approval by the Board, except as provided in Board Orders 
adopted by the Board.
    (b) Voting. The Board votes on items of business in meetings 
conducted pursuant to the Government in the Sunshine Act. Alternatively, 
whenever a Member of the Board is of the opinion that joint deliberation 
among the members of the Board upon any matter at a meeting is 
unnecessary in light of the nature of the matter, impracticable, or 
would impede the orderly disposition of agency business, such matter may 
be disposed of by employing notation voting procedures. A written 
notation of the vote of each participating Board member shall be 
recorded by the General Counsel who shall retain it in the records of 
the Board. If a Board member votes to calendar a notation item in 
accordance with applicable Board Orders, the Board must consider the 
calendared notation item at a public meeting of the Board within 90 days 
of the date on which the item is calendared. This section does not 
permit a notation item to be calendared other than as provided in 
applicable Board Orders. A notation vote to schedule a public meeting or 
a special meeting may not be calendared. The Chairperson shall add any 
calendared notation item to the agenda for the next CSB public meeting 
if one is to occur within 90 days or schedule a special meeting to 
consider any calendared notation item no later than 90 days from the 
calendar action. Any disagreement about whether a notation item has been 
calendared effectively in accordance with applicable Board Orders shall 
be decided by the Board.
    (c) Public meetings and agendas. The Chairperson, or in the absence 
of a chairperson, a member designated by the Board, shall schedule a 
minimum of four public meetings per year in Washington, DC, to take 
place during the months of October, January, April, and July.
    (1) Agenda. The Chairperson, or in the absence of a chairperson, a 
member designated by the Board, shall be responsible for preparation of 
a final meeting agenda. The final agenda may not differ in substance 
from the items published in the Sunshine Act notice for that meeting. 
Any member may submit agenda items related to CSB business for 
consideration at any public meeting, and the Chairperson shall include 
such items on the agenda. At a minimum, each quarterly meeting shall 
include the following agenda items:
    (i) Consideration and vote on any notation items calendared since 
the date of the last public meeting; and
    (ii) A review by the Board of the schedule for completion of all 
open investigations, studies, and other important work of the Board.
    (2) Publication of agenda information. The Chairperson shall be 
responsible for posting information related to any agenda item that is 
appropriate for public release on the CSB Web site no less than two days 
prior to a public meeting.

[68 FR 65403, Nov. 20, 2003, as amended at 80 FR 46824, Aug. 6, 2015; 88 
FR 36256, June 2, 2023]



Sec.  1600.6  Office location.

    The principal offices of the Chemical Safety and Hazard 
Investigation Board

[[Page 699]]

are located at 1750 Pennsylvania Avenue NW, Suite 910, Washington, DC 
20006.

[88 FR 36257, June 2, 2023]



PART 1601_PROCEDURES FOR DISCLOSURE OF RECORDS UNDER THE
FREEDOM OF INFORMATION ACT--Table of Contents



               Subpart A_Purpose, Scope, and Applicability

Sec.
1601.1 Purpose and scope.
1601.2 Applicability.

       Subpart B_Procedures for Requesting and Disclosing Records

1601.10 Proactive disclosures.
1601.11 Requirements for making requests.
1601.12 Responsibility for responding to requests.
1601.13 Timing of responses to requests.
1601.14 Responses to requests.
1601.15 Special procedures for confidential commercial information.

                            Subpart C_Appeals

1601.20 Processing of appeals.

                        Subpart D_Administration

1601.30 Protection of records.
1601.31 Preservation of records pertaining to requests under this part.
1601.32 Other rights and services.

                             Subpart E_Fees

1601.40 Procedures for fees.

    Authority: 5 U.S.C. 552.

    Source: 82 FR 45502, Sept. 29, 2017, unless otherwise noted.



               Subpart A_Purpose, Scope, and Applicability



Sec.  1601.1  Purpose and scope.

    (a) In general. This part contains the Chemical Safety and Hazard 
Investigation Board (``CSB'' or ``agency'') regulations implementing the 
Freedom of Information Act (``FOIA''), 5 U.S.C. 552. These regulations 
provide the procedures by which members of the public may obtain access 
to records compiled, created, and maintained by the CSB, along with the 
CSB procedures for responding to such requests. The rules in this 
subpart are to be read in conjunction with the FOIA and the Uniform 
Freedom of Information Fee Schedule and Guidelines published by the 
White House Office of Management and Budget (OMB Guidelines).
    (b) Definitions.
    (1) Chairperson means the Chairperson of the CSB.
    (2) Chief FOIA Officer means the person designated by Chairperson 
who has overall responsibility for the CSB's compliance with the FOIA.
    (3) FOIA Officer means a person designated by the Chief FOIA Officer 
to process requests for the CSB documents under the FOIA.
    (4) Record means information regardless of its physical form or 
characteristics including information created, stored, and retrievable 
by electronic means that is created or obtained by the CSB and under the 
control of the CSB at the time of the request, including information 
maintained for the CSB by an entity under Government contract for 
records management purposes. Record includes any writing, drawing, map, 
recording, tape, film, photo, or other documentary material by which 
information is preserved.
    (5) Requester means any person, including an individual, Indian 
tribe, partnership, corporation, association, or public or private 
organization other than a Federal agency that requests access to records 
in the possession of the CSB pursuant to 5 U.S.C. 552.



Sec.  1601.2  Applicability.

    (a) In general. The FOIA and the regulations in this part apply to 
all CSB documents and information. However, if another law sets specific 
procedures for disclosure that supersede the FOIA, then CSB must process 
a request in accordance with the procedures that apply to those specific 
documents. If a request is received for disclosure of a document to the 
public that is not required to be released under the provisions of law 
other than the FOIA, then the CSB must consider the request under the 
FOIA and the regulations in this part. Requests made by individuals for 
records about themselves under the Privacy Act of 1974, 5 U.S.C. 552a, 
are processed in accordance with CSB's Privacy Act regulations (part 
1602 of

[[Page 700]]

this chapter), as well as under this subpart.
    (b) Disclosure of requested records. The CSB will only withhold 
information under the FOIA if the agency reasonably foresees that 
disclosure would harm an interest protected by an exemption or 
disclosure is prohibited by law. The FOIA Officer will make requested 
records available to the public to the greatest extent possible in 
keeping with the FOIA, except for the following types of records, which 
are exempt from the disclosure requirements:
    (1) Records specifically authorized under criteria established by an 
Executive Order (E.O.) to be kept secret in the interest of national 
defense or foreign policy and which are, in fact, properly classified 
pursuant to such E.O.;
    (2) Records related solely to the internal personnel rules and 
practices of the CSB;
    (3) Records specifically exempted from disclosure by statute (other 
than 5 U.S.C. 552(b)) provided that such statute requires that the 
matters be withheld from the public in such a manner as to leave no 
discretion on the issue or that the statute establishes particular 
criteria for withholding information or refers to particular types of 
matters to be withheld; and if enacted after the date of enactment of 
the OPEN FOIA Act of 2009, specifically cites to 5 U.S.C. 552(b)(3);
    (4) Records containing trade secrets and commercial or financial 
information obtained from a person and privileged or confidential;
    (5) Interagency or intra-agency memoranda or letters which would not 
be available by law to a party other than an agency in litigation with 
the CSB, provided that the deliberative process privilege shall not 
apply to records created twenty-five (25) years or more before the date 
on which the records were requested;
    (6) Personnel and medical files and similar files the disclosure of 
which would constitute a clearly unwarranted invasion of personal 
privacy;
    (7) Records or information compiled for law enforcement purposes, 
but only to the extent that the production of such law enforcement 
records or information:
    (i) Could reasonably be expected to interfere with enforcement 
proceedings;
    (ii) Would deprive a person of a right to a fair trial or an 
impartial adjudication;
    (iii) Could reasonably be expected to constitute an unwarranted 
invasion of personal privacy;
    (iv) Could reasonably be expected to disclose the identity of a 
confidential source, including a State, local or foreign agency or 
authority or any private institution which furnished information on a 
confidential basis, and in the case of a record or information compiled 
by criminal law enforcement authority in the course of a criminal 
investigation or by an agency conducting a lawful national security 
intelligence investigation, information furnished by a confidential 
source;
    (v) Would disclose techniques and procedures for law enforcement 
investigations or prosecutions, or would disclose guidelines for law 
enforcement investigations or prosecutions if such disclosure could 
reasonably be expected to risk circumvention of the law; or
    (vi) Could reasonably be expected to endanger the life or physical 
safety of any individual.
    (8) Records contained in or related to examination, operating, or 
condition reports prepared by, or on behalf of, or for the use of an 
agency responsible for the regulation or supervision of financial 
institutions;
    (9) Geological or geophysical information and data, including maps, 
concerning wells.
    (c) Disclosure of segregable nonexempt material. The CSB will 
consider whether partial disclosure of information is possible whenever 
the agency determines that a full disclosure of a requested record is 
not possible. If a requested record contains exempted material along 
with nonexempted material, all reasonably segregable nonexempt material 
must be disclosed.
    (d) Records available through routine distribution procedures. If 
the record requested includes material published and offered for sale, 
e.g., by the Superintendent of Documents of the Government Printing 
Office, or by an authorized private distributor, then the CSB

[[Page 701]]

will refer the requester to those sources. Nevertheless, if the 
requester is not satisfied with the alternative sources, then the CSB 
will process the request under its usual FOIA procedures, noting that 
the CSB will likely withhold copyrighted records under Exemption 4.



       Subpart B_Procedures for Requesting and Disclosing Records



Sec.  1601.10  Proactive disclosures.

    (a) In general. Records that the FOIA requires the CSB to make 
available for public inspection in an electronic format may be accessed 
through the CSB's Web site (which can be found at http://www.csb.gov/
disclaimers /legal-affairs-foia/). The CSB is responsible for 
determining which of its records must be made publicly available, for 
identifying additional records of interest to the public that are 
appropriate for public disclosure, and for posting and indexing such 
records. The CSB must ensure that its Web site of posted records and 
indices is reviewed and updated on an ongoing basis. The CSB has a FOIA 
Contact and FOIA Public Liaison who can assist individuals in locating 
records particular to the CSB. The most up to date contact information 
for the CSB's FOIA Contact and the CSB's FOIA Public Liaison is 
available at http://www.foia.gov/report-makerequest.html.
    (b) Definitions.
    (1) Disclose or disclosure means making records available for 
examination or copying, or furnishing a copy of nonexempt responsive 
records.
    (2) FOIA Contact means the name, address and phone number at the CSB 
where a requester can make a FOIA request.
    (3) FOIA Public Liaison means the official who supervises the FOIA 
Requester Service Center.



Sec.  1601.11  Requirements for making requests.

    (a) General information. (1) To make a request for records, a 
requester should write directly to the FOIA office of the agency that 
maintains the records sought. A request will receive the quickest 
possible response if the request is addressed to the FOIA office of the 
agency that maintains the records sought. If the CSB is the agency that 
maintains the records sought, then the contact information for the CSB's 
FOIA office is listed at http://www.foia.gov/report-makerequest.html, 
and any additional requirements for submitting a request can be found 
herein. Additionally, requesters who have questions or concerns about 
making a request, and those who have made a request who have questions 
or concerns, may discuss their request(s) with the CSB's FOIA Contact or 
FOIA Public Liaison.
    (2) A requester who is making a request for records about himself or 
herself must comply with the verification of identity requirements 
described in this section. Requesters must provide either a notarized 
statement or a statement signed under penalty of perjury stating that 
the requester is the person they claim to be. This certification is 
required in order to protect the requester's privacy and to ensure that 
private information about the requester is not disclosed inappropriately 
to another individual.
    (3) Where a request for records pertains to a third party, a 
requester may receive greater access by submitting either a notarized 
authorization signed by that individual or a declaration made in 
compliance with the requirements set forth in 28 U.S.C. 1746 by that 
individual authorizing disclosure of the records to the requester, or by 
submitting proof that the individual is deceased (e.g., a copy of a 
death certificate or an obituary). As an exercise of administrative 
discretion, the CSB can require a requester to supply additional 
information, if necessary, in order to verify that a particular 
individual has consented to disclosure.
    (b) Addressing requests. (1) All requests for records to the CSB 
must be made in writing.
    (2) For hard copy requests: The envelope and the request both should 
be clearly marked ``FOIA Request'' and addressed to: Chief FOIA 
Officer--FOIA Request, Chemical Safety and Hazard Investigation Board, 
1750 Pennsylvania Ave. NW., Suite 910, Washington, DC 20006.

[[Page 702]]

    (3) For electronic requests: The subject line of the request should 
be marked ``FOIA Request'' and the request may be submitted by email to 
[email protected].
    (4) A request that is improperly addressed will be deemed to have 
been received by the CSB on the date that it is actually received by the 
CSB, or would have been received with the exercise of due diligence, by 
the FOIA Officer.
    (c) Description of records sought. (1) Requesters must describe the 
records sought in sufficient detail to enable the CSB's personnel to 
locate them with a reasonable amount of effort.
    (2) To the extent possible, requesters should include specific 
information that may help the CSB identify the requested records, such 
as the date, title or name, author, recipient, subject matter of the 
record, case number, file designation, or reference number. In general, 
requesters should include as much detail as possible about the specific 
records or the types of records that they are seeking. Before submitting 
their requests, requesters may contact the CSB's FOIA Contact or FOIA 
Public Liaison to discuss the records they seek and to receive 
assistance in describing the records.
    (3) If, after receiving a request, the CSB determines that the 
request does not reasonably describe the records sought, then the CSB 
must inform the requester what additional information is needed or why 
the request is otherwise insufficient. Requesters who are attempting to 
reformulate or modify such a request may discuss their request with the 
CSB's FOIA Contact or with the CSB's FOIA Public Liaison. If a request 
does not reasonably describe the records sought, the CSB's response to 
the request may be delayed.
    (d) Form of records. Requests may specify the preferred form or 
format (including electronic formats) for the records that the requester 
seeks. The CSB must accommodate requests if the record is readily 
reproducible in that form or format. If a person seeks information from 
the CSB in a format that does not currently exist, then the CSB must 
make reasonable efforts to provide the information in the format 
requested. The CSB will not create a new record of information to 
satisfy a request.
    (e) Contact information. Requesters must provide their first and 
last name along with their contact information, such as their phone 
number, email address, and/or mailing address, to assist the CSB in 
communicating with them and providing released records.
    (f) Agreement to pay fees. The CSB considers a FOIA request an 
agreement by the requester to pay all applicable fees charged unless the 
requester seeks a waiver of fees. The CSB ordinarily will confirm this 
agreement in an acknowledgement letter. The CSB will not charge any fee 
if the total cost of the response is less than $25.00. See Sec.  1601.40 
[discussing fees in more detail]. If the fee will be greater than 
$25.00, then the CSB must contact the requester to discuss how the 
requester wants to proceed.
    (g) Types of records not available. The FOIA does not require the 
CSB to:
    (1) Compile or create records solely for the purpose of satisfying a 
request for records;
    (2) Provide records not yet in existence, even if such records may 
be expected to come into existence at some future time; or
    (3) Restore records destroyed or otherwise disposed of, except that 
the FOIA Officer must notify the requester that the requested records 
have been destroyed or otherwise disposed of.



Sec.  1601.12  Responsibility for responding to requests.

    (a) In general. The agency that first receives a request for a 
record and maintains that record is the agency responsible for 
responding to the request. In determining which records are responsive 
to a request, the CSB ordinarily will include only records in its 
possession as of the date that it begins its search. If any other date 
is used, the CSB must inform the requester of that date. A record that 
is excluded from the requirements of the FOIA pursuant to 5 U.S.C. 
552(c), is not considered responsive to a request.
    (b) Authority to grant or deny requests. The Chief FOIA Officer or a 
designee is

[[Page 703]]

authorized to grant or to deny any initial request for records that are 
maintained by the CSB and to determine any appropriate fees.
    (c) Consultation, referral, and coordination. When reviewing 
records, the CSB must determine whether another agency of the Federal 
Government is better able to determine whether the record is exempt from 
disclosure under the FOIA. As to any such record, the CSB must proceed 
in one of the following ways:
    (1) Consultation. When records originated with the CSB, but contain 
within them information of interest to another agency or other Federal 
Government office, the CSB should consult with that other entity prior 
to making a release determination.
    (2) Referral. (i) When the CSB believes that a different agency or 
component of a different agency is best able to determine whether to 
disclose the record, the CSB should refer the responsibility for 
responding to the request regarding that record to that agency or 
component. Ordinarily, the agency that originated the record is presumed 
to be the best agency to make the disclosure determination. However, if 
the CSB and the originating agency jointly agree that the CSB is in the 
best position to respond regarding the record, then the record may be 
handled as a consultation.
    (ii) Whenever the CSB refers any part of the responsibility for 
responding to a request to another agency, it must document the 
referral, maintain a copy of the record that it refers, and notify the 
requester of the referral, informing the requester of the name(s) of the 
agency to which the record was referred, including that agency's FOIA 
contact information.
    (3) Coordination. The standard referral procedure is not appropriate 
where disclosure of the identity of the agency to which the referral 
would be made could harm an interest protected by an applicable 
exemption, such as the exemptions that protect personal privacy or 
national security interests. For example, if a non-law enforcement 
agency responding to a request for records on a living third party 
locates within its files records originating with a law enforcement 
agency, and if the existence of that law enforcement interest in the 
third party was not publicly known, then to disclose that law 
enforcement interest could cause an unwarranted invasion of the personal 
privacy of the third party. Similarly, if an agency locates within its 
files material originating with an Intelligence Community agency, and 
the involvement of that agency in the matter is classified and not 
publicly acknowledged, then to disclose or give attribution to the 
involvement of that Intelligence Community agency could cause national 
security harms. In such instances, in order to avoid harm to an interest 
protected by an applicable exemption, the CSB must coordinate with the 
originating agency to seek its views on whether the record can be 
disclosed. The release determination for the record that is the subject 
of the coordination will then be conveyed to the requester by the CSB.
    (d) Classified information. Upon receipt of any request involving 
classified information, the CSB must determine whether the information 
is currently and properly classified in accordance with applicable 
classification rules. Whenever a request involves a record containing 
information that has been classified or may be appropriate for 
classification by another agency under any applicable E.O. concerning 
the classification of records, the CSB must refer the responsibility for 
responding to the request regarding that information to the agency that 
classified the information, or to the agency that should consider the 
information for classification. Whenever the CSB's record contains 
information that has been derivatively classified (for example, when it 
contains information classified by another agency), the CSB must refer 
the responsibility for responding to that portion of the request to the 
agency that classified the underlying information.
    (e) Timing of responses to consultations and referrals. All 
consultations and referrals received by the CSB must be handled 
according to the date that the first agency received the perfected FOIA 
request.
    (f) Agreements regarding consultations and referrals. The CSB may 
establish agreements with other agencies to

[[Page 704]]

eliminate the need for consultations or referrals with respect to 
particular types of records.
    (g) No responsive record. If no records are responsive to the 
request, the FOIA Officer will so notify the requester in writing.



Sec.  1601.13  Timing of responses to requests.

    (a) In general. The CSB ordinarily will respond to requests 
according to their order of receipt.
    (b) Definitions.
    (1) Working day means a Federal workday; Saturdays, Sundays, and 
Federal holidays are excluded in computing the response time for 
processing FOIA requests.
    (2) [Reserved]
    (c) Multitrack processing. The CSB has a specific track for requests 
that are granted expedited processing, in accordance with the standards 
set forth in paragraph (f) of this section. In addition, the CSB uses 
two standard processing tracks- one for simple requests and a separate 
track for complex requests. The CSB will assign requests to the simple 
or complex track based on the estimated amount of work or time needed to 
process the request. Among the factors the CSB may consider are the 
number of records requested, the number of pages involved in processing 
the request and the need for consultations or referrals. The CSB must 
advise each requester of the track into which their request falls and, 
when appropriate, will offer a requester an opportunity to narrow or 
modify their request so that it can be placed in the simple processing 
track.
    (d) Unusual circumstances. Whenever the CSB cannot meet the 
statutory time limit for processing a request because of ``unusual 
circumstances,'' as defined in the FOIA, and the CSB extends the time 
limit on that basis, the CSB must, before expiration of the twenty (20) 
day period to respond, notify the requester in writing of the unusual 
circumstances involved and of the date by which the CSB estimates 
processing of the request will be completed. Where the extension exceeds 
ten (10) working days, the CSB must, as described by the FOIA, provide 
the requester with an opportunity to modify the request or arrange an 
alternative time period for processing the original or modified request. 
The CSB must make available its designated FOIA Contact or its FOIA 
Public Liaison for this purpose. A list of agency FOIA Public Liaisons 
is available at http://www.foia.gov/report-makerequest.html. The CSB 
must also alert requesters to the availability of the Office of 
Government Information Services (OGIS) to provide dispute resolution 
services.
    (e) Aggregating requests. To satisfy unusual circumstances under the 
FOIA, the CSB may aggregate requests in cases where it reasonably 
appears that multiple requests, submitted either by a requester, or by a 
group of requesters acting in concert, constitute a single request that 
would otherwise involve unusual circumstances. The CSB must not 
aggregate multiple requests that involve unrelated matters.
    (f) Expedited processing. (1) The CSB must process requests and 
appeals on an expedited basis whenever it is determined that they 
involve:
    (i) Circumstances in which the lack of expedited processing could 
reasonably be expected to pose an imminent threat to the life or 
physical safety of an individual;
    (ii) An urgency to inform the public about an actual or alleged 
Federal Government activity, if made by a person who is primarily 
engaged in disseminating information;
    (iii) The loss of substantial due process rights; or
    (iv) A matter of widespread and exceptional media interest in which 
there exists possible questions about the government's integrity that 
affect public confidence.
    (2) A request for expedited processing may be made at any time. 
Requests based on paragraphs (f)(1)(i) through (iv) of this section must 
be submitted to the CSB. When making a request for expedited processing 
of an administrative appeal, the request must be submitted to the CSB's 
FOIA Appeals Officer in accordance with Sec.  1601.20.
    (3) A requester who seeks expedited processing must submit a 
statement, certified to be true and correct, explaining in detail the 
basis for making the request for expedited processing.

[[Page 705]]

For example, under paragraph (f)(1)(ii) of this section, a requester who 
is not a full-time member of the news media must establish that the 
requester is a person whose primary professional activity or occupation 
is information dissemination, though it need not be the requester's sole 
occupation. Such a requester also must establish a particular urgency to 
inform the public about the government activity involved in the 
request--one that extends beyond the public's right to know about 
government activity generally. The existence of numerous articles 
published on a given subject can be helpful in establishing the 
requirement that there be an ``urgency to inform'' the public on the 
topic. As a matter of administrative discretion, the CSB may waive the 
formal certification requirement.
    (4) The CSB must notify the requester within ten (10) calendar days 
of the receipt of a request for expedited processing of its decision 
whether to grant or deny expedited processing. If expedited processing 
is granted, then the request must be given priority, placed in the 
processing track for expedited requests, and must be processed as soon 
as practicable. If a request for expedited processing is denied, then 
the CSB must act on any appeal of that decision expeditiously.



Sec.  1601.14  Responses to requests.

    (a) In general. The CSB, to the extent practicable, will communicate 
electronically with requesters having access to the Internet, such as by 
email or web portal.
    (b) Acknowledgments of requests. The CSB must acknowledge the 
request in writing and assign it an individualized tracking number if it 
will take longer than ten (10) working days to process. The CSB must 
include in the acknowledgment a brief description of the records sought 
to allow requesters to more easily keep track of their requests.
    (c) Estimated dates of completion and interim responses. Upon 
request, the CSB must provide an estimated date by which the CSB expects 
to provide a response to the requester. If a request involves a 
voluminous amount of material, or searches in multiple locations, the 
CSB may provide interim responses, releasing the records on a rolling 
basis.
    (d) Grants of requests. Once the CSB determines it will grant a 
request in full or in part, it must notify the requester in writing. The 
notice must describe the manner in which the record or records will be 
disclosed, whether by providing a copy of the record or records with the 
response, or providing them at a later date, or by making a copy of the 
record available to the requester for inspection at a reasonable time 
and place. The procedure for such an inspection must not unreasonably 
disrupt the operation of the CSB. The CSB must also inform the requester 
of any fees charged under Sec.  1601.40 and must disclose the requested 
records to the requester promptly upon payment of any applicable fees. 
The CSB must inform the requester of the availability of its FOIA Public 
Liaison to offer assistance.
    (e) Adverse determinations of requests. If the CSB makes an adverse 
determination denying a request in any respect, it must notify the 
requester of that determination in writing. Adverse determinations, or 
denials of requests, include decisions that: The requested record is 
exempt, in whole or in part; the request does not reasonably describe 
the records sought; the information requested is not a record subject to 
the FOIA; the requested record does not exist, cannot be located, or has 
been destroyed; or the requested record is not readily reproducible in 
the form or format sought by the requester. Adverse determinations also 
include denials involving fees or fee waiver matters or denials of 
requests for expedited processing.
    (f) Content of denial. The denial must be signed by the Chairperson 
or the FOIA Officer and must include:
    (1) The name and title or position of the person responsible for the 
denial;
    (2) A brief statement of the reasons for the denial, including any 
FOIA exemption(s) applied by the CSB in denying the request;
    (3) An estimate of the volume of any records or information 
withheld, such as the number of pages or some other

[[Page 706]]

reasonable form of estimation, although such an estimate is not required 
if the volume is otherwise indicated by deletions marked on records that 
are disclosed in part or if providing an estimate would harm an interest 
protected by an applicable exemption; and
    (4) A statement that the denial may be appealed under Sec.  1601.20, 
and a description of the appeal requirements.
    (5) A statement notifying the requester of the assistance available 
from the CSB's FOIA Public Liaison and the dispute resolution services 
offered by the OGIS.
    (g) Markings on released documents. Records disclosed in part must 
be marked clearly to show the amount of information deleted and the 
exemption under which the deletion was made unless doing so would harm 
an interest protected by an applicable exemption. The location of the 
information deleted must also be indicated on the record, if technically 
feasible.
    (h) Use of record exclusions. (1) In the event that the CSB 
identifies records that may be subject to exclusion from the 
requirements of the FOIA pursuant to 5 U.S.C. 552(c), the CSB must 
confer with Department of Justice, Office of Information Policy (OIP), 
to obtain approval to apply the exclusion.
    (2) When invoking an exclusion, the CSB must maintain an 
administrative record of the process of invocation and approval of the 
exclusion by OIP.



Sec.  1601.15  Special procedures for confidential commercial information.

    (a) In general. Confidential commercial information provided to the 
CSB by a submitter must not be disclosed pursuant to a FOIA request 
except in accordance with this section.
    (b) Definitions.
    (1) Confidential commercial information means commercial or 
financial information obtained by the CSB from a submitter that may be 
protected from disclosure under Exemption 4 of the FOIA, 5 U.S.C. 
552(b)(4).
    (2) Submitter means any person or entity, including a corporation, 
State, or foreign government, Indian tribal governments but not 
including another Federal Government entity, that provides confidential 
commercial information, either directly or indirectly to the Federal 
Government.
    (c) Designation of confidential commercial information. A submitter 
of confidential commercial information must make good faith efforts to 
designate by appropriate markings, at the time of submission, any 
portion of its submission that it considers to be protected from 
disclosure under Exemption 4 of the FOIA, 5 U.S.C. 552(b)(4). These 
designations expire ten (10) years after the date of the submission 
unless the submitter requests and provides justification for a longer 
designation period.
    (d) When notice to submitters is required. (1) The CSB must promptly 
provide written notice to the submitter of confidential commercial 
information whenever records containing such information are requested 
under the FOIA if the CSB determines that it may be required to disclose 
the records, provided:
    (i) The requested information has been designated in good faith by 
the submitter as information considered protected from disclosure under 
Exemption 4; or
    (ii) The CSB has a reason to believe that the requested information 
may be protected from disclosure under Exemption 4, but has not yet 
determined whether the information is protected from disclosure.
    (2) The notice must either describe the commercial information 
requested or include a copy of the requested records or portions of 
records containing the information. In cases involving a voluminous 
number of submitters, the CSB may post or publish a notice in a place or 
manner reasonably likely to inform the submitters of the proposed 
disclosure, instead of sending individual notifications.
    (e) Exceptions to submitter notice requirements. The notice 
requirements of this section do not apply if:
    (1) The CSB determines that the information is exempt under the 
FOIA, and therefore will not be disclosed;
    (2) The information has been lawfully published or has been 
officially made available to the public;
    (3) Disclosure of the information is required by a statute other 
than the

[[Page 707]]

FOIA or by a regulation issued in accordance with the requirements of 
E.O. 12600 of June 23, 1987; or
    (4) The designation made by the submitter under paragraph (c) of 
this section appears obviously frivolous. In such case, the CSB must 
give the submitter written notice of any final decision to disclose the 
information within a reasonable number of days prior to a specified 
disclosure date.
    (f) Opportunity to object to disclosure. (1) The CSB must specify a 
reasonable time period within which the submitter must respond to the 
notice referenced above.
    (2) If a submitter has any objections to disclosure, it should 
provide the CSB a detailed written statement that specifies all grounds 
for withholding the particular information under any exemption of the 
FOIA. In order to rely on Exemption 4 as basis for nondisclosure, the 
submitter must explain why the information constitutes a trade secret or 
commercial or financial information that is privileged or confidential. 
Whenever possible, the business submitter's claim of confidentiality 
should be supported by a statement or certification by an officer or 
authorized representative of the business submitter. Information 
provided by a submitter pursuant to this paragraph may itself be subject 
to disclosure under the FOIA.
    (3) A submitter who fails to respond within the time period 
specified in the notice will be considered to have no objection to 
disclosure of the information. The CSB is not required to consider any 
information received after the date of any disclosure decision. Any 
information provided by a submitter under this subpart may itself be 
subject to disclosure under the FOIA.
    (g) Analysis of objections. The CSB must consider a submitter's 
objections and specific grounds for nondisclosure in deciding whether to 
disclose the requested information.
    (h) Notice of intent to disclose. Whenever the CSB decides to 
disclose information over the objection of a submitter, the CSB must 
provide the submitter written notice, which must include:
    (1) A statement of the reasons why each of the submitter's 
disclosure objections was not sustained;
    (2) A description of the information to be disclosed or copies of 
the records as the CSB intends to release them; and
    (3) A specified disclosure date, which must be a reasonable time 
after the notice.
    (i) Notice of FOIA lawsuit. Whenever a requester files a lawsuit 
seeking to compel the disclosure of confidential commercial information, 
the CSB must promptly notify the submitter.
    (j) Requester notification. The CSB must notify the requester 
whenever it provides the submitter with notice and an opportunity to 
object to disclosure because the request includes information that may 
arguably be exempt from disclosure under Exemption 4 of the FOIA; 
whenever it notifies the submitter of its intent to disclose the 
requested information; and whenever a submitter files a lawsuit to 
prevent the disclosure of the information.



                            Subpart C_Appeals



Sec.  1601.20  Processing of appeals.

    (a) Right of appeal. If a request has been denied in whole or in 
part, the requester may appeal the denial to the CSB's FOIA Appeals 
Officer.
    (b) Definitions.
    (1) FOIA Appeal means an independent review of an adverse 
determination initial determination made in response to a FOIA request.
    (2) FOIA Appeals Officer means the person designated by the 
Chairperson to process and to decide a FOIA appeal.
    (c) Requirements for making an appeal. (1) A requester may appeal 
any adverse determinations to the FOIA Appeals Officer. Examples of 
adverse determinations are provided in Sec.  1601.14(e).
    (2) The requester must make the appeal in writing. Requesters can 
submit appeals by mail or email in accordance with the following 
requirements herein, which are also listed on the CSB's Web site. To 
facilitate handling, the requester should mark both the appeal letter 
and envelope, or subject line of the electronic transmission, ``Freedom 
of Information Act Appeal'' or ``FOIA Appeal.''

[[Page 708]]

    (i) For hard copy requests: The envelope and the request both should 
addressed to: FOIA Appeals Officer--FOIA Appeal, Chemical Safety and 
Hazard Investigation Board, 1750 Pennsylvania Ave. NW., Suite 910, 
Washington, DC 20006.
    (ii) For electronic requests: The appeal should addressed to the 
FOIA Appeals Officer and may be submitted by email to 
[email protected].
    (3) To be considered timely, an appeal must be postmarked, or in the 
case of electronic submissions, transmitted, within ninety (90) calendar 
days after the date of the adverse determination that is the subject of 
the appeal. For purposes of apply the ninety (90) calendar day deadline, 
the CSB will treat an appeal that is improperly addressed as being 
received on the date on the date that it is actually received by the 
CSB, or would have been received with the exercise of due diligence, by 
the FOIA Appeals Officer.
    (4) The appeal should clearly identify the adverse determination 
that is being appealed and the assigned request number.
    (5) An appeal should also include a copy of the initial request, a 
copy of the letter denying the request in whole or in part, and a 
statement of the circumstances, reasons, or arguments advanced in 
support of disclosure of the requested record.
    (d) Adjudication of appeals. (1) The CSB FOIA Appeals Officer or 
designee will act on behalf of the CSB's Chief FOIA Officer on all 
appeals under this section.
    (2) An appeal ordinarily will not be adjudicated if the request 
becomes a matter of FOIA litigation.
    (3) On receipt of any appeal involving classified information, the 
FOIA Appeals Officer must take appropriate action to ensure compliance 
with applicable classification rules.
    (e) Decisions on appeals. The CSB must provide its decision on an 
appeal in writing. The disposition of an appeal will be in writing and 
will constitute the final action of the CSB on a request. A decision 
that upholds the CSB's determination in whole or in part will contain a 
statement that identifies the reasons for the affirmance, including any 
FOIA exemptions applied. The decision will provide the requester with 
notification of the statutory right to file a lawsuit and will also 
inform the requester of the mediation services offered by the OGIS of 
the National Archives and Records Administration as a non-exclusive 
alternative to litigation. If the CSB's decision is remanded or modified 
on appeal, the CSB must notify the requester of that determination in 
writing. The CSB must then further process the request in accordance 
with that appeal determination and will respond directly to the 
requester.
    (f) Engaging in dispute resolution services provided by OGIS. 
Dispute resolution is a voluntary process. If the CSB agrees to 
participate in the dispute resolution services provided by OGIS, it will 
actively engage as a partner to the process in an attempt to resolve the 
dispute.
    (g) When appeal is required. Before seeking review by a court of the 
CSB's adverse determination, a requester generally must first submit a 
timely administrative appeal.



                        Subpart D_Administration



Sec.  1601.30  Protection of records.

    (a) In general. (1) Except as authorized by this part or as 
otherwise necessary in performing official duties, CSB employees must 
not disclose or permit disclosure of any document or information in the 
possession of the CSB that is confidential or otherwise of a nonpublic 
nature, including that regarding the CSB, the Environmental Protection 
Agency or the Occupational Safety and Health Administration.
    (2) No person may, without permission, remove from the place where 
it is made available any record made available to him for inspection or 
copying. Stealing, altering, mutilating, obliterating, or destroying a 
Federal record, in whole or in part, is a violation of Federal law.
    (b) [Reserved]



Sec.  1601.31  Preservation of records pertaining to requests under this part.

    The CSB must preserve all correspondence pertaining to the requests 
that it receives under this subpart, as well as copies of all requested 
records,

[[Page 709]]

until disposition or destruction is authorized pursuant to title 44 of 
the United States Code and the General Records Schedule 4.2 of the 
National Archives and Records Administration. The CSB must not dispose 
of or destroy records while they are the subject of a pending request, 
appeal, or lawsuit under the FOIA.



Sec.  1601.32  Other rights and services.

    Nothing in this subpart will be construed to entitle any person, as 
of right, to any service or to the disclosure of any record to which 
such person is not entitled under the FOIA.



                             Subpart E_Fees



Sec.  1601.40  Procedures for fees.

    (a) In general. The CSB must charge for processing requests under 
the FOIA in accordance with the provisions of this section and with the 
OMB Guidelines. For purposes of assessing fees, the FOIA establishes 
three categories of requesters: Commercial use requesters, non-
commercial scientific or educational institutions or news media 
requesters, and all other requesters. Different fees are assessed 
depending on the category. Requesters may seek a fee waiver. The CSB 
must consider requests for fee waivers in accordance with the 
requirements in paragraph (k) of this section. To resolve any fee issues 
that arise under this section, the CSB may contact a requester for 
additional information. The CSB must ensure that searches, review, and 
duplication are conducted in the most efficient and the least expensive 
manner. The CSB ordinarily will collect all applicable fees before 
sending copies of records to a requester. Requesters must pay fees by 
check or money order made payable to the Treasury of the United States, 
or by another method as determined by the CSB.
    (b) Definitions.
    (1) Commercial use request is a request that asks for information 
for a use or a purpose that furthers a commercial, trade, or profit 
interest, which can include furthering those interests through 
litigation. The CSB's decision to place a requester in the commercial 
use category will be made on a case-by-case basis based on the 
requester's intended use of the information. The CSB must notify 
requesters of their placement in this category.
    (2) Direct costs are those expenses that the CSB incurs in searching 
for and duplicating (and, in the case of commercial use requests, 
reviewing) records in order to respond to a FOIA request. For example, 
direct costs include the salary of the employee performing the work 
(i.e., the basic rate of pay for the employee, plus sixteen percent 
(16%) of that rate to cover benefits) and the cost of operating 
computers and other electronic equipment, such as photocopiers and 
scanners. Direct costs do not include overhead expenses such as the 
costs of space, and of heating or lighting a facility.
    (3) Duplication is reproducing a copy of a record, or of the 
information contained in it, necessary to respond to a FOIA request. 
Copies can take the form of paper, audiovisual materials, or electronic 
records, among others. The copies provided must be in a form that is 
reasonably usable by requesters.
    (4) Educational institution is any school that operates a program of 
scholarly research. A requester in this fee category must show that the 
request is made in connection with the requester's role at the 
educational institution. The CSB may seek verification from the 
requester that the request is in furtherance of scholarly research and 
the CSB must advise requesters of their placement in this category.
    (i) Example 1. A request from a professor of geology at a university 
for records relating to soil erosion, written on letterhead of the 
Department of Geology, would be presumed to be from an educational 
institution.
    (ii) Example 2. A request from the same professor of geology seeking 
drug information from the Food and Drug Administration in furtherance of 
a murder mystery he is writing would not be presumed to be an 
institutional request, regardless of whether it was written on 
institutional stationery.
    (iii) Example 3. A student who makes a request in furtherance of the 
student's coursework or other school-sponsored activities and provides a 
copy of a course syllabus or other reasonable documentation to indicate 
the

[[Page 710]]

research purpose for the request, would qualify as part of this fee 
category.
    (5) Noncommercial scientific institution is an institution that is 
not operated on a ``commercial'' basis, as defined in paragraph (b)(1) 
of this section and that is operated solely for the purpose of 
conducting scientific research the results of which are not intended to 
promote any particular product or industry. A requester in this category 
must show that the request is authorized by and is made under the 
auspices of a qualifying institution and that the records are sought to 
further scientific research and are not for a commercial use. The CSB 
must advise requesters of their placement in this category.
    (6) Representative of the news media is any person or entity that 
gathers information of potential interest to a segment of the public, 
uses its editorial skills to turn the raw materials into a distinct 
work, and distributes that work to an audience. Accordingly, the term 
includes any person actively gathering news for an entity that is 
organized and operated to publish or broadcast news to the public. The 
term news means information that is about current events or that would 
be of current interest to the public. Examples of news media entities 
include television or radio stations that broadcast news to the public 
at large, and publishers of periodicals that disseminate news and make 
their products available through a variety of means to the general 
public, including news organizations that make their products available 
for purchase by or subscription by or free distribution to the general 
public, including those solely on the Internet. These examples are not 
all-inclusive. Moreover, as methods of news delivery evolve (for 
example, the adoption of the electronic dissemination of newspapers 
through telecommunications services), such alternative media shall be 
considered to be news-media entities. A request for records supporting 
the news-dissemination function of the requester will not be considered 
to be for a commercial use. Freelance journalists who demonstrate a 
solid basis for expecting publication through a news media entity will 
be considered as a representative of the news media. A publishing 
contract would provide the clearest evidence that publication is 
expected; however, the CSB can also consider a requester's past 
publication record in making this determination. The CSB will advise 
requesters of their placement in this category.
    (7) Review is the examination of a record located in response to a 
FOIA request in order to determine whether any portion of it is exempt 
from disclosure under one or more of the FOIA exemptions. Review time 
includes processing any record for disclosure, such as doing all that is 
necessary to prepare the record for disclosure, including the process of 
redacting the record and marking the appropriate exemptions. Review 
costs are properly charged even if a record ultimately is not disclosed. 
Review time also includes time spent both obtaining and considering any 
formal objection to disclosure made by a confidential commercial 
information submitter under Sec.  1601.15, but it does not include time 
spent resolving general legal or policy issues regarding the application 
of exemptions.
    (8) Search is the process of looking for and retrieving records or 
information responsive to a request. Search time includes page-by-page 
or line-by-line identification of information within records and the 
reasonable efforts expended to locate and retrieve information from 
electronic records.
    (c) Charging fees. In responding to FOIA requests, the CSB will 
charge the following fees unless a waiver or reduction of fees has been 
granted under paragraph (k) of this section. Because the fee amounts 
provided below already account for the direct costs associated with a 
given fee type, the CSB should not add any additional costs to charges 
calculated under this section.
    (1) Search. (i) Requests made by educational institutions, 
noncommercial scientific institutions, or representatives of the news 
media are not subject to search fees. The CSB must charge search fees 
for all other requesters, subject to the restrictions of paragraph (d) 
of this section. The CSB may properly charge for time spent searching 
even if they do not locate any responsive records or if they determine 
that the records are entirely exempt from disclosure.

[[Page 711]]

    (ii) For each quarter hour spent by personnel searching for 
requested records, including electronic searches that do not require new 
programming, the fees will be charged as follows: $6.00 for clerical 
personnel; $11.00 for professional personnel; and $15.00 for managerial 
personnel.
    (iii) The CSB must charge the direct costs associated with 
conducting any search that requires the creation of a new computer 
program to locate the requested records. The CSB must notify the 
requester of the costs associated with creating such a program, and the 
requester must agree to pay the associated costs before the costs may be 
incurred.
    (iv) For requests that require the retrieval of records stored by 
the CSB at a Federal records center operated by the National Archives 
and Records Administration (NARA), the CSB must charge additional costs 
in accordance with the Transactional Billing Rate Schedule established 
by NARA.
    (2) Duplication. The CSB will charge duplication fees to all 
requesters, subject to the restrictions of paragraph (d) of this 
section. The CSB must honor a requester's preference for receiving a 
record in a particular form or format where the CSB can readily 
reproduce it in the form or format requested. Where photocopies are 
supplied, the CSB must provide one copy per request at the cost of $0.17 
per page. For copies of records produced on tapes, disks, or other 
media, the CSB must charge the direct costs of producing the copy, 
including operator time. Where paper documents must be scanned in order 
to comply with a requester's preference to receive the records in an 
electronic format, the requester must also pay the direct costs 
associated with scanning those materials. For other forms of 
duplication, the CSB must charge the direct costs.
    (3) Review. The CSB must charge review fees to requesters who make 
commercial use requests. Review fees will be assessed in connection with 
the initial review of the record, i.e., the review conducted by the CSB 
to determine whether an exemption applies to a particular record or 
portion of a record. No charge will be made for review at the 
administrative appeal stage of exemptions applied at the initial review 
stage. However, if a particular exemption is deemed to no longer apply, 
any costs associated with the CSB's re-review of the records in order to 
consider the use of other exemptions may be assessed as review fees. 
Review fees will be charged at the same rates as those charged for a 
search under paragraph (c)(1)(ii) of this section.
    (d) Restrictions on charging fees. (1) When the CSB determines that 
a requester is an educational institution, non-commercial scientific 
institution, or representative of the news media, and the records are 
not sought for commercial use, it will not charge search fees.
    (2)(i) If the CSB fails to comply with the FOIA's time limits in 
which to respond to a request, it may not charge search fees, or, in the 
instances of requests from requesters described in paragraph (d)(1) of 
this section, may not charge duplication fees, except as described in 
paragraphs (d)(2)(ii)-(iv).
    (ii) If the CSB has determined that unusual circumstances as defined 
by the FOIA apply and the CSB provided timely written notice to the 
requester in accordance with the FOIA, a failure to comply with the time 
limit must be excused for an additional ten (10) days.
    (iii) If the CSB has determined that unusual circumstances as 
defined by the FOIA apply, and more than 5,000 pages are necessary to 
respond to the request, the CSB may charge search fees, or, in the case 
of requesters described in paragraph (d)(1) of this section, may charge 
duplication fees, if the following steps are taken. The CSB must have 
provided timely written notice of unusual circumstances to the requester 
in accordance with the FOIA and the CSB must have discussed with the 
requester via written mail, email, or telephone (or made not less than 
three good-faith attempts to do so) how the requester could effectively 
limit the scope of the request in accordance with 5 U.S.C. 
552(a)(6)(B)(ii). If this exception is satisfied, the CSB may charge all 
applicable fees incurred in the processing of the request.
    (iv) If a court has determined that exceptional circumstances exist 
as defined by the FOIA, a failure to comply with the time limits shall 
be excused

[[Page 712]]

for the length of time provided by the court order.
    (3) No search or review fees will be charged for a quarter-hour 
period unless more than half of that period is required for search or 
review.
    (4) Except for requesters seeking records for a commercial use, the 
CSB must provide without charge:
    (i) The first 100 pages of duplication (or the cost equivalent for 
other media); and
    (ii) The first two hours of search.
    (5) No fee will be charged when the total fee, after deducting the 
100 free pages (or its cost equivalent) and the first two hours of 
search, is equal to or less than $25.00.
    (e) Notice of anticipated fees in excess of $25.00. (1) When the CSB 
determines or estimates that the fees to be assessed in accordance with 
this section will exceed $25.00, the CSB must notify the requester of 
the actual or estimated amount of the fees, including a breakdown of the 
fees for search, review or duplication, unless the requester has 
indicated a willingness to pay fees as high as those anticipated. If 
only a portion of the fee can be estimated readily, the CSB must advise 
the requester accordingly. If the request is for non-commercial use, the 
notice will specify that the requester is entitled to the statutory 
entitlements of 100 pages of duplication at no charge and, if the 
requester is charged search fees, two hours of search time at no charge, 
and will advise the requester whether those entitlements have been 
provided.
    (2) If the CSB notifies the requester that the actual or estimated 
fees are in excess of $25.00, the request will not be considered 
received and further work will not be completed until the requester 
commits in writing to pay the actual or estimated total fee, or 
designates some amount of fees the requester is willing to pay, or in 
the case of a non-commercial use requester who has not yet been provided 
with the requester's statutory entitlements, designates that the 
requester seeks only that which can be provided by the statutory 
entitlements. The requester must provide the commitment or designation 
in writing, and must, when applicable, designate an exact dollar amount 
the requester is willing to pay. The CSB is not required to accept 
payments in installments. Requesters must respond to their fee estimate 
within thirty (30) working days, or the CSB will assume that the 
requester is no longer interested in their FOIA request(s), and the case 
will be administratively closed.
    (3) If the requester has indicated a willingness to pay some 
designated amount of fees, but the CSB estimates that the total fee will 
exceed that amount, the CSB will toll the processing of the request when 
it notifies the requester of the estimated fees in excess of the amount 
the requester has indicated a willingness to pay. The CSB will inquire 
whether the requester wishes to revise the amount of fees the requester 
is willing to pay or modify the request. Once the requester responds, 
the time to respond will resume from where it was at the date of the 
notification.
    (4) The CSB must make available its FOIA Public Liaison or anther 
FOIA professional to assist any requester in reformulating a request to 
meet the requester's needs at a lower cost.
    (f) Charges for other services. Although not required to provide 
special services, if the CSB chooses to do so as a matter of 
administrative discretion, the direct costs of providing the service 
will be charged. Examples of such services include certifying that 
records are true copies, providing multiple copies of the same document, 
or sending records by means other than first class mail.
    (g) Charging interest. The CSB may charge interest on any unpaid 
bill starting on the thirty-first (31) day following the date of billing 
the requester. Interest charges will be assessed at the rate provided in 
31 U.S.C. 3717 and will accrue from the billing date until payment is 
received by the CSB. The CSB must follow the provisions of the Debt 
Collection Act of 1982 (Pub. L. 97-365, 96 Stat. 1749), as amended, and 
its administrative procedures, including the use of consumer reporting 
agencies, collection agencies, and offset.
    (h) Aggregating requests. When the CSB reasonably believes that a 
requester or a group of requesters acting

[[Page 713]]

in concert is attempting to divide a single request into a series of 
requests for the purpose of avoiding fees, the CSB may aggregate those 
requests and charge accordingly. The CSB may presume that multiple 
requests of this type made within a thirty (30) day period have been 
made in order to avoid fees. For requests separated by a longer period, 
the CSB must aggregate them only where there is a reasonable basis for 
determining that aggregation is warranted in view of all the 
circumstances involved. Multiple requests involving unrelated matters 
cannot be aggregated.
    (i) Advance payments. (1) For requests other than those described in 
paragraphs (i)(2) or (i)(3) of this section, the CSB must not require 
the requester to make an advance payment before work is commenced or 
continued on a request. Payment owed for work already completed (i.e., 
payment before copies are sent to a requester) is not an advance 
payment.
    (2) When the CSB determines or estimates that a total fee to be 
charged under this section will exceed $250.00, it may require that the 
requester make an advance payment up to the amount of the entire 
anticipated fee before beginning to process the request. The CSB may 
elect to process the request prior to collecting fees when it receives a 
satisfactory assurance of full payment from a requester with a history 
of prompt payment.
    (3) Where a requester has previously failed to pay a properly 
charged FOIA fee to the CSB within thirty (30) calendar days of the 
billing date, the CSB may require that the requester pay the full amount 
due, plus any applicable interest on that prior request, and the CSB may 
require that the requester make an advance payment of the full amount of 
any anticipated fee before the CSB begins to process a new request or 
continues to process a pending request or any pending appeal. Where the 
CSB has a reasonable basis to believe that a requester has 
misrepresented the requester's identity in order to avoid paying 
outstanding fees, it may require that the requester provide proof of 
identity.
    (4) In cases in which the CSB requires advance payment, the request 
will not be considered received and further work will not be completed 
until the required payment is received. If the requester does not pay 
the advance payment within thirty (30) calendar days after the date of 
the CSB's fee determination, the request will be closed.
    (j) Other statutes specifically providing for fees. The fee schedule 
of this section does not apply to fees charged under any statute that 
specifically requires the CSB to set and collect fees for particular 
types of records. In instances where records responsive to a request are 
subject to a statutorily-based fee schedule program, the CSB must inform 
the requester of the contact information for that program.
    (k) Requirements for waiver or reduction of fees. (1) Requesters may 
seek a waiver of fees by submitting a written application demonstrating 
how disclosure of the requested information is in the public interest 
because it is likely to contribute significantly to public understanding 
of the operations or activities of the government and is not primarily 
in the commercial interest of the requester.
    (2) The CSB must furnish records responsive to a request without 
charge or at a reduced rate when it determines, based on all available 
information, that disclosure of the requested information is in the 
public interest because it is likely to contribute significantly to 
public understanding of the operations or activities of the government 
and is not primarily in the commercial interest of the requester. In 
deciding whether this standard is satisfied the CSB must consider the 
factors described in paragraphs (k)(2)(i) through (iii) of this section:
    (i) Disclosure of the requested information would shed light on the 
operations or activities of the government. The subject of the request 
must concern identifiable operations or activities of the Federal 
Government with a connection that is direct and clear, not remote or 
attenuated.
    (ii) Disclosure of the requested information is likely to contribute 
significantly to public understanding of those operations or activities. 
This factor is satisfied when the following criteria are met:

[[Page 714]]

    (A) Disclosure of the requested records must be meaningfully 
informative about government operations or activities. The disclosure of 
information that already is in the public domain, in either the same or 
a substantially identical form, would not be meaningfully informative if 
nothing new would be added to the public's understanding.
    (B) The disclosure must contribute to the understanding of a 
reasonably broad audience of persons interested in the subject, as 
opposed to the individual understanding of the requester. A requester's 
expertise in the subject area as well as the requester's ability and 
intention to effectively convey information to the public must be 
considered. The CSB will presume that a representative of the news media 
will satisfy this consideration.
    (iii) The disclosure must not be primarily in the commercial 
interest of the requester. To determine whether disclosure of the 
requested information is primarily in the commercial interest of the 
requester, the CSB must consider the following criteria:
    (A) The CSB must identify whether the requester has any commercial 
interest that would be furthered by the requested disclosure. A 
commercial interest includes any commercial, trade, or profit interest. 
Requesters must be given an opportunity to provide explanatory 
information regarding this consideration.
    (B) If there is an identified commercial interest, the CSB must 
determine whether that is the primary interest furthered by the request. 
A waiver or reduction of fees is justified when the requirements of 
paragraphs (k)(2)(i) and (ii) are satisfied and any commercial interest 
is not the primary interest furthered by the request. The CSB ordinarily 
will presume that when a news media requester has satisfied the factors 
in paragraphs (k)(2)(i) and (ii) of this section, the request is not 
primarily in the commercial interest of the requester. Disclosure to 
data brokers or others who merely compile and market government 
information for direct economic return will not be presumed to primarily 
serve the public interest.
    (3) Where only some of the records to be released satisfy the 
requirements for a waiver of fees, a waiver must be granted for those 
records.
    (4) Requests for a waiver or reduction of fees should be made when 
the request is first submitted to the CSB and should address the 
criteria referenced above. A requester may submit a fee waiver request 
at a later time so long as the underlying record request is pending or 
on administrative appeal. When a requester who has committed to pay fees 
subsequently asks for a waiver of those fees and that waiver is denied, 
the requester must pay any costs incurred up to the date the fee waiver 
request was received.



PART 1602_PROTECTION OF PRIVACY AND ACCESS TO INDIVIDUAL 
RECORDS UNDER THE PRIVACY ACT OF 1974--Table of Contents



Sec.
1602.1 General provisions.
1602.2 Requests for access to records.
1602.3 Responsibility for responding to requests for access to records.
1602.4 Responses to requests for access to records.
1602.5 Appeals from denials of requests for access to records.
1602.6 Requests for amendment or correction of records.
1602.7 Requests for accountings of record disclosures.
1602.8 Preservation of records.
1602.9 Fees.
1602.10 Notice of court-ordered and emergency disclosures.

    Authority: 5 U.S.C. 552a, 553; 42 U.S.C. 7412 et seq.

    Source: 66 FR 17080, Mar. 29, 2001, unless otherwise noted.



Sec.  1602.1  General provisions.

    (a) Purpose and scope. This part contains the rules that the 
Chemical Safety and Hazard Investigation Board (``CSB'' or ``Board'') 
follows under the Privacy Act of 1974, 5 U.S.C. 552a. These rules should 
be read together with the Privacy Act, which provides additional 
information about records maintained on individuals. The rules in this 
part apply to all records in systems of records maintained by the CSB 
that are retrieved by an individual's name or personal identifier. They 
describe

[[Page 715]]

the procedures by which individuals may request access to records about 
themselves, request amendment or correction of those records, and 
request an accounting of disclosures of those records by the CSB. In 
addition, the CSB processes all Privacy Act requests for access to 
records under the Freedom of Information Act (FOIA), 5 U.S.C. 552, 
following the rules contained in part 1601 of this chapter, which gives 
requests the benefit of both statutes.
    (b) Definitions. As used in this part:
    Requester means an individual who makes a request for access, a 
request for amendment or correction, or a request for an accounting 
under the Privacy Act.
    Request for access to a record means a request made as described in 
subsection (d)(1) of the Privacy Act, 5 U.S.C. 552a.
    Request for amendment or correction of a record means a request made 
as described in subsection (d)(2) of the Privacy Act, 5 U.S.C. 552a.
    Request for an accounting means a request made as described in 
subsection (c)(3) of the Privacy Act, 5 U.S.C. 552a.



Sec.  1602.2  Requests for access to records.

    (a) How made and addressed. You may make a request for access to a 
CSB record about yourself by appearing in person or by writing to the 
CSB. Your request should be sent or delivered to the CSB's General 
Counsel, at 2175 K Street, NW., 4th Floor, Washington, DC 20037. For the 
quickest possible handling, you should mark both your request letter and 
the envelope ``Privacy Act Request.''
    (b) Description of records sought. You must describe the records 
that you want in enough detail to enable CSB personnel to locate the 
system of records containing them with a reasonable amount of effort. 
Whenever possible, your request should describe the records sought, the 
time periods in which you believe they were compiled, and the name or 
identifying number of each system of records in which you believe they 
are kept. The CSB publishes notices in the Federal Register that 
describe its systems of records. A description of the CSB's systems of 
records also may be found as part of the ``Privacy Act Compilation'' 
published by the National Archives and Records Administration's Office 
of the Federal Register. This compilation is available in most large 
reference and university libraries. This compilation also can be 
accessed electronically at the Government Printing Office's World Wide 
Web site (which can be found at http://www.access.gpo.gov /su__docs).
    (c) Agreement to pay fees. If you make a Privacy Act request for 
access to records, it shall be considered an agreement by you to pay all 
applicable fees charged under Sec.  1602.9 up to $25.00. The CSB 
ordinarily will confirm this agreement in an acknowledgment letter. When 
making a request, you may specify a willingness to pay a greater or 
lesser amount.
    (d) Verification of identity. When you make a request for access to 
records about yourself, you must verify your identity. You must state 
your full name, current address, and date and place of birth. You must 
sign your request and your signature must either be notarized or 
submitted by you under 28 U.S.C. 1746, a law that permits statements to 
be made under penalty of perjury as a substitute for notarization. In 
order to help the identification and location of requested records, you 
may also, at your option, include your social security number.
    (e) Verification of guardianship. When making a request as the 
parent or guardian of a minor or as the guardian of someone determined 
by a court to be incompetent, for access to records about that 
individual, you must establish:
    (1) The identity of the individual who is the subject of the record, 
by stating the name, current address, date and place of birth, and, at 
your option, the social security number of the individual;
    (2) Your own identity, as required in paragraph (d) of this section;
    (3) That you are the parent or guardian of that individual, which 
you may prove by providing a copy of the individual's birth certificate 
showing your parentage or by providing a court order establishing your 
guardianship; and
    (4) That you are acting on behalf of that individual in making the 
request.

[[Page 716]]



Sec.  1602.3  Responsibility for responding to requests for access to records.

    (a) In general. In determining which records are responsive to a 
request, the CSB ordinarily will include only those records in its 
possession as of the date the CSB begins its search for them. If any 
other date is used, the CSB will inform the requester of that date.
    (b) Authority to grant or deny requests. The CSB's General Counsel, 
or his/her designee, is authorized to grant or deny any request for 
access to a record of the CSB.
    (c) Consultations and referrals. When the CSB receives a request for 
access to a record in its possession, it will determine whether another 
agency of the Federal Government is better able to determine whether the 
record is exempt from access under the Privacy Act. If the CSB 
determines that it is best able to process the record in response to the 
request, then it will do so. If the CSB determines that it is not best 
able to process the record, then it will either:
    (1) Respond to the request regarding that record, after consulting 
with the agency best able to determine whether the record is exempt from 
access and with any other agency that has a substantial interest in it; 
or
    (2) Refer the responsibility for responding to the request regarding 
that record to another agency that originated the record (but only if 
that agency is subject to the Privacy Act). Ordinarily, the agency that 
originated a record will be presumed to be best able to determine 
whether it is exempt from access.
    (d) Notice of referral. Whenever the CSB refers all or any part of 
the responsibility for responding to your request to another agency, it 
ordinarily will notify you of the referral and inform you of the name of 
each agency to which the request has been referred and of the part of 
the request that has been referred.
    (e) Timing of responses to consultations and referrals. All 
consultations and referrals shall be handled according to the date the 
Privacy Act access request was initially received by the CSB, not any 
later date.



Sec.  1602.4  Responses to requests for access to records.

    (a) Acknowledgments of requests. On receipt of your request, the CSB 
ordinarily will send an acknowledgment letter, which shall confirm your 
agreement to pay fees under Sec.  1602.2(c) and may provide an assigned 
request number for further reference.
    (b) Grants of requests for access. Once the CSB makes a 
determination to grant your request for access in whole or in part, it 
will notify you in writing. The CSB will inform you in the notice of any 
fee charged under Sec.  1602.9 and will disclose records to you promptly 
on payment of any applicable fee. If your request is made in person, the 
CSB may disclose records to you directly, in a manner not unreasonably 
disruptive of its operations, on payment of any applicable fee and with 
a written record made of the grant of the request. If you are 
accompanied by another person when you make a request in person, you 
shall be required to authorize in writing any discussion of the records 
in the presence of the other person.
    (c) Adverse determinations of requests for access. If the CSB makes 
an adverse determination denying your request for access in any respect, 
it will notify you of that determination in writing. Adverse 
determinations, or denials of requests, consist of: a determination to 
withhold any requested record in whole or in part; a determination that 
a requested record does not exist or cannot be located; a determination 
that what has been requested is not a record subject to the Privacy Act; 
a determination on any disputed fee matter; and a denial of a request 
for expedited treatment. The notification letter shall be signed by the 
General Counsel, or his/her designee, and shall include:
    (1) The name and title or position of the person responsible for the 
denial;
    (2) A brief statement of the reason(s) for the denial, including any 
Privacy Act exemption(s) applied by the CSB in denying the request; and
    (3) A statement that the denial may be appealed under Sec.  
1602.5(a) and a description of the requirements of Sec.  1602.5(a).

[[Page 717]]



Sec.  1602.5  Appeals from denials of requests for access to records.

    (a) Appeals. If you are dissatisfied with the CSB's response to your 
request for access to records, you may appeal an adverse determination 
denying your request in any respect to the Privacy Act Appeals Officer 
of the CSB, 2175 K Street, NW., Suite 400, Washington, DC 20037. You 
must make your appeal in writing, and it must be received within 60 days 
of the date of the letter denying your request. Your appeal letter may 
include as much or as little related information as you wish, as long as 
it clearly identifies the determination (including the assigned request 
number, if any) that you are appealing. For the quickest possible 
handling, you should mark both your appeal letter and the envelope 
``Privacy Act Appeal.''
    (b) Responses to appeals. The decision on your appeal will be made 
in writing. A decision affirming an adverse determination in whole or in 
part will include a brief statement of the reason(s) for the affirmance, 
including any Privacy Act exemption applied, and will inform you of the 
Privacy Act provisions for court review of the decision. If the adverse 
determination is reversed or modified on appeal in whole or in part, you 
will be notified in a written decision and your request will be 
reprocessed in accordance with that appeal decision.
    (c) When appeal is required. If you wish to seek review by a court 
of any adverse determination or denial of a request, you must first 
appeal it under this section.



Sec.  1602.6  Requests for amendment or correction of records.

    (a) How made and addressed. You may make a request for amendment or 
correction of a CSB record about yourself by following the procedures in 
Sec.  1602.2. Your request should identify each particular record in 
question, state the amendment or correction that you want, and state why 
you believe that the record is not accurate, relevant, timely, or 
complete. You may submit any documentation that you think would be 
helpful.
    (b) CSB responses. Within ten working days of receiving your request 
for amendment or correction of records, the CSB will send you a written 
acknowledgment of its receipt of your request, and it will promptly 
notify you whether your request is granted or denied. If the CSB grants 
your request in whole or in part, it will describe the amendment or 
correction made and advise you of your right to obtain a copy of the 
corrected or amended record. If the CSB denies your request in whole or 
in part, it will send you a letter stating:
    (1) The reason(s) for the denial; and
    (2) The procedure for appeal of the denial under paragraph (c) of 
this section, including the name and business address of the official 
who will act on your appeal.
    (c) Appeals. You may appeal a denial of a request for amendment or 
correction in the same manner as a denial of a request for access to 
records (see Sec.  1602.5), and the same procedures will be followed. If 
your appeal is denied, you will be advised of your right to file a 
Statement of Disagreement as described in paragraph (d) of this section 
and of your right under the Privacy Act for court review of the 
decision.
    (d) Statements of Disagreement. If your appeal under this section is 
denied in whole or in part, you have the right to file a Statement of 
Disagreement that states your reason(s) for disagreeing with the CSB's 
denial of your request for amendment or correction. Statements of 
Disagreement must be concise, must clearly identify each part of any 
record that is disputed, and should be no longer than one typed page for 
each fact disputed. Your Statement of Disagreement must be sent to the 
CSB, which will place it in the system of records in which the disputed 
record is maintained and will mark the disputed record to indicate that 
a Statement of Disagreement has been filed and where in the system of 
records it may be found.
    (e) Notification of amendment/correction or disagreement. Within 30 
working days of the amendment or correction of a record, the CSB shall 
notify all persons, organizations, or agencies to which it previously 
disclosed the record, if an accounting of that disclosure was made, that 
the record has

[[Page 718]]

been amended or corrected. If an individual has filed a Statement of 
Disagreement, the CSB will attach a copy of it to the disputed record 
whenever the record is disclosed and may also attach a concise statement 
of its reason(s) for denying the request to amend or correct the record.



Sec.  1602.7  Requests for an accounting of record disclosures.

    (a) How made and addressed. Except where accountings of disclosures 
are not required to be kept (as stated in paragraph (b) of this 
section), you may make a request for an accounting of any disclosure 
that has been made by the CSB to another person, organization, or agency 
of any record about you. This accounting contains the date, nature, and 
purpose of each disclosure, as well as the name and address of the 
person, organization, or agency to which the disclosure was made. Your 
request for an accounting should identify each particular record in 
question and should be made by writing to the CSB, following the 
procedures in Sec.  1602.2.
    (b) Where accountings are not required. The CSB is not required to 
provide accountings to you where they relate to disclosures for which 
accountings are not required to be kept---in other words, disclosures 
that are made to employees within the agency and disclosures that are 
made under the FOIA.
    (c) Appeals. You may appeal a denial of a request for an accounting 
to the CSB Appeals Officer in the same manner as a denial of a request 
for access to records (see Sec.  1602.5) and the same procedures will be 
followed.



Sec.  1602.8  Preservation of records.

    The CSB will preserve all correspondence pertaining to the requests 
that it receives under this part, as well as copies of all requested 
records, until disposition or destruction is authorized by Title 44 of 
the United States Code or the National Archives and Records 
Administration's General Records Schedule 14. Records will not be 
disposed of while they are the subject of a pending request, appeal, or 
lawsuit under the Privacy Act.



Sec.  1602.9  Fees.

    The CSB will charge fees for duplication of records under the 
Privacy Act in the same way in which it charges duplication fees under 
the FOIA (see part 1601, subpart D of this chapter). No search or review 
fee will be charged for any record.



Sec.  1602.10  Notice of court-ordered and emergency disclosures.

    (a) Court-ordered disclosures. When a record pertaining to an 
individual is required to be disclosed by a court order, the CSB will 
make reasonable efforts to provide notice of this to the individual. 
Notice will be given within a reasonable time after the CSB's receipt of 
the order--except that in a case in which the order is not a matter of 
public record, the notice will be given only after the order becomes 
public. This notice will be mailed to the individual's last known 
address and will contain a copy of the order and a description of the 
information disclosed.
    (b) Emergency disclosures. Upon disclosing a record pertaining to an 
individual made under compelling circumstances affecting health or 
safety, the CSB will notify that individual of the disclosure. This 
notice will be mailed to the individual's last known address and will 
state the nature of the information disclosed; the person, organization, 
or agency to which it was disclosed; the date of disclosure; and the 
compelling circumstances justifying the disclosure.



PART 1603_RULES IMPLEMENTING THE GOVERNMENT IN THE SUNSHINE ACT--Table of Contents



Sec.
1603.1 Applicability.
1603.2 Policy.
1603.3 Definitions.
1603.4 Open meetings requirement.
1603.5 Assurance of compliance.
1603.6 Business requiring a meeting.
1603.7 Grounds on which meetings may be closed or information may be 
          withheld.
1603.8 Procedures for closing meetings, or withholding information, and 
          requests by affected persons to close a meeting.
1603.9 Procedures for public announcement of meetings.
1603.10 Changes following public announcement.

[[Page 719]]

1603.11 Transcripts, recordings, or minutes of closed meetings.
1603.12 Availability of transcripts, recordings, and minutes, and 
          applicable fees.
1603.13 Report to Congress.
1603.14 Severability.

    Authority: 5 U.S.C. 552b; 42 U.S.C. 7412(r)(6)(N).

    Source: 67 FR 35445, May 20, 2002, unless otherwise noted.



Sec.  1603.1  Applicability.

    (a) This part implements the provisions of the Government in the 
Sunshine Act, 5 U.S.C. 552b. These procedures apply to meetings, as 
defined herein, of the Members of the Chemical Safety and Hazard 
Investigation Board (``CSB'' or ``Board'').
    (b) This part does not affect the procedures by which CSB records 
are made available to the public, which continue to be governed by part 
1601 of this chapter pursuant to the Freedom of Information Act, 5 
U.S.C. 552, except that the exemptions set forth in Sec.  1603.7 shall 
govern in the case of any requests made for the transcripts, recordings, 
and minutes described in Sec.  1603.11.



Sec.  1603.2  Policy.

    It is the policy of the CSB to provide the public with the fullest 
practicable information regarding the decisionmaking processes of the 
Board, while protecting the rights of individuals and the ability of the 
Board to discharge its statutory functions and responsibilities. The 
public is invited to attend but not to participate in open meetings. For 
any open meeting, the Board, by majority vote, may decide to allow for a 
public comment period immediately following the close of that meeting.



Sec.  1603.3  Definitions.

    As used in this part:
    (a) Days means calendar days, except where noted otherwise.
    (b) General Counsel means the Board's principal legal officer, or a 
CSB attorney serving as Acting General Counsel.
    (c) Meeting means the deliberations of at least a quorum of Members 
where such deliberations determine or result in the joint conduct or 
disposition of official CSB business, and includes conference telephone 
calls or other exchanges otherwise coming within the definition. A 
meeting does not include:
    (1) Notation voting or similar consideration of business, whether by 
circulation of material to the Members individually in writing or by a 
polling of the Members individually by telephone.
    (2) Action by at least a quorum of Members to:
    (i) Open or to close a meeting or to release or to withhold 
information pursuant to Sec.  1603.7;
    (ii) Set an agenda for a proposed meeting(s);
    (iii) Call a meeting on less than seven days' notice as permitted by 
Sec.  1603.9(b); or
    (iv) Change the subject matter or the determination to open or to 
close a publicly announced meeting under Sec.  1603.10(b).
    (3) A session attended by at least a quorum of Members for the 
purpose of having the Board's staff or expert consultants to the Board 
brief or otherwise provide information to the Board concerning any 
matters within the purview of the Board under its authorizing statute, 
provided that the Board does not engage in deliberations that determine 
or result in the joint conduct or disposition of official CSB business 
on such matters.
    (4) A session attended by at least a quorum of Members for the 
purpose of having the Environmental Protection Agency or Occupational 
Safety and Health Administration (including contractors of those 
agencies) or other persons or organizations brief or otherwise provide 
information to the Board concerning any matters within the purview of 
the Board under its authorizing statute, provided that the Board does 
not engage in deliberations that determine or result in the joint 
conduct or disposition of official CSB business on such matters.
    (5) A gathering of Members for the purpose of holding informal 
preliminary discussions or exchange of views which do not effectively 
predetermine official action.
    (d) Member means an individual duly appointed and confirmed to the 
collegial body known as the Board.
    (e) Reporter means a CSB employee designated by the General Counsel,

[[Page 720]]

under Sec.  1603.5(c), to attend and prepare a written summary of all 
briefings described in paragraphs (c)(3) and (c)(4) of this section and 
all informal preliminary discussions described in paragraph (c)(5) of 
this section.
    (f) Sunshine Act means the Government in the Sunshine Act, 5 U.S.C. 
552b.



Sec.  1603.4  Open meetings requirement.

    Any meetings of the Board, as defined in Sec.  1603.3, shall be 
conducted in accordance with this part. Except as provided in Sec.  
1603.7, the Board's meetings, or portions thereof, shall be open to 
public observation.



Sec.  1603.5  Assurance of compliance.

    (a) The General Counsel or another attorney designated by the 
General Counsel will attend and monitor all briefings described in Sec.  
1603.3(c)(3) and (c)(4) and all informal preliminary discussions 
described in Sec.  1603.3(c)(5), to assure that those gatherings do not 
proceed to the point of becoming deliberations and meetings for Sunshine 
Act purposes.
    (b) The General Counsel or the designated attorney will inform the 
Board Members if developing discussions at a briefing or gathering 
should be deferred until a notice of an open or closed meeting can be 
published in the Federal Register, and a meeting conducted pursuant to 
the Sunshine Act and this part.
    (c) For each briefing described in Sec.  1603.3(c)(3) or (c)(4) and 
each informal preliminary discussion described in Sec.  1603.3(c)(5), 
the General Counsel is hereby authorized to designate a CSB employee, 
other than the attorney referred to in paragraph (a) of this section, to 
serve as a reporter. An employee may be designated as reporter for a 
single briefing or informal discussion or for a series of briefings or 
discussions. The reporter shall attend and prepare a written summary of 
each briefing(s) or informal discussion(s) for which he/she has been 
designated. The reporter must prepare the summary of a particular 
briefing or informal discussion within five business days after the date 
of that briefing or discussion. The reporter must then submit the 
summary to the General Counsel or the designated attorney who attended 
the briefing or informal discussion that is the subject of the summary 
for review and approval as a fair and accurate summary of that briefing 
or discussion. The written summaries of briefings and informal 
discussions shall be maintained in the Office of General Counsel.



Sec.  1603.6  Business requiring a meeting.

    The Board may, by majority vote of its Members, determine that 
particular items or classes of Board business cannot be accomplished by 
notation voting, but must instead be decided by a recorded vote at a 
meeting, as defined in Sec.  1603.3(c).



Sec.  1603.7  Grounds on which meetings may be closed or information
may be withheld.

    Except in a case where the Board finds that the public interest 
requires otherwise, a meeting may be closed and information pertinent to 
such meeting otherwise required by Sec. Sec.  1603.8, 1603.9, and 
1603.10 to be disclosed to the public may be withheld if the Board 
properly determines that such meeting or portion thereof or the 
disclosure of such information is likely to:
    (a) Disclose matters that are:
    (1) Specifically authorized under criteria established by an 
Executive Order to be kept secret in the interests of national defense 
or foreign policy; and
    (2) In fact, properly classified pursuant to such Executive Order. 
In making the determination that this exemption applies, the Board shall 
rely upon the classification assigned to a document by the Environmental 
Protection Agency, Occupational Safety and Health Administration, or 
other originating agency;
    (b) Relate solely to the internal personnel rules and practices of 
the CSB;
    (c) Disclose matters specifically exempted from disclosure by 
statute (other than 5 U.S.C. 552), provided that such statute:
    (1) Requires that the matters be withheld from the public in such a 
manner as to leave no discretion on the issue; or
    (2) Establishes particular criteria for withholding or refers to 
particular types of matters to be withheld;

[[Page 721]]

    (d) Disclose trade secrets and commercial or financial information 
obtained from a person and privileged or confidential;
    (e) Involve accusing any person of a crime, or formally censuring 
any person;
    (f) Disclose information of a personal nature where disclosure would 
constitute a clearly unwarranted invasion of personal privacy;
    (g) Disclose investigatory records compiled for law enforcement 
purposes, or information which if written would be contained in such 
records, but only to the extent that the production of such records or 
information would:
    (1) Interfere with enforcement proceedings;
    (2) Deprive a person of a right to a fair trial or an impartial 
adjudication;
    (3) Constitute an unwarranted invasion of personal privacy;
    (4) Disclose the identity of a confidential source and, in the case 
of a record compiled by a criminal law enforcement authority in the 
course of a criminal investigation or by an agency conducting a lawful 
national security intelligence investigation, confidential information 
furnished only by the confidential source;
    (5) Disclose investigative techniques and procedures; or
    (6) Endanger the life or physical safety of law enforcement 
personnel;
    (h) Disclose information the premature disclosure of which would be 
likely to significantly frustrate implementation of a proposed action of 
the CSB, except that this paragraph shall not apply in any instance 
where the Board has already disclosed to the public the content or 
nature of its proposed action or is required by law to make such 
disclosure on its own initiative prior to taking final action on such 
proposal;
    (i) Specifically concern the Board's issuance of a subpoena, or the 
CSB's participation in a civil action or proceeding, an action in a 
foreign court or international tribunal, or an arbitration, or the 
initiation, conduct, or disposition by the CSB of a particular case of 
formal agency adjudication pursuant to the procedures in 5 U.S.C. 554 or 
otherwise involving a determination on the record after opportunity for 
a hearing; or
    (j) Disclose other information for which the Government in the 
Sunshine Act provides an exemption to the open meeting requirements of 
that Act.



Sec.  1603.8  Procedures for closing meetings, or withholding 
information, and requests by affected persons to close a meeting.

    (a) A meeting shall not be closed, or information pertaining thereto 
withheld, unless a majority of all Members votes to take such action. A 
majority of the Board may act by taking a single vote with respect to 
any action under Sec.  1603.7. A single vote is permitted with respect 
to a series of meetings, a portion or portions of which are proposed to 
be closed to the public, or with respect to any information concerning 
such series of meetings, so long as each meeting in such series involves 
the same particular subject matters and is scheduled to be held no more 
than thirty days after the initial meeting in such series. Each Member's 
vote under this paragraph shall be recorded and proxies are not 
permitted.
    (b) Any person whose interest may be directly affected if a portion 
of a meeting is open may request the Board to close that portion on any 
of the grounds referred to in Sec.  1603.7(e) through (g). Requests, 
with reasons in support thereof, should be submitted in writing, no 
later than two days before the meeting in question, to the General 
Counsel, Chemical Safety and Hazard Investigation Board, 2175 K Street, 
NW., Suite 400, Washington, DC 20037. In motion of any Member, the Board 
shall determine by recorded vote whether to grant the request.
    (c) Within one working day of any vote taken pursuant to this 
section, the CSB shall make available a written copy of such vote 
reflecting the vote of each Member on the question and, if a portion of 
a meeting is to be closed to the public, a full written explanation of 
its action closing the meeting and a list of all persons expected to 
attend and their affiliation.
    (d) Before every closed meeting, the General Counsel of the CSB 
shall publicly certify that, in his/her opinion,

[[Page 722]]

the meeting may be closed to the public and shall state each relevant 
exemption provision. If the General Counsel invokes the exemption for 
classified or sensitive unclassified information under Sec.  1603.7(a), 
he/shall rely upon the classification or designation assigned to the 
document containing such information by the Environmental Protection 
Agency, Occupational Safety and Health Administration, or other 
originating agency. A copy of such certification, together with a 
statement setting forth the time and place of the meeting and the 
persons present, shall be retained by the Board as part of the 
transcript, recording, or minutes required by Sec.  1603.11.



Sec.  1603.9  Procedures for public announcement of meetings.

    (a) For each meeting, the CSB shall make public announcement, at 
least one week before the meeting, of:
    (1) The time of the meeting;
    (2) The place of the meeting;
    (3) The subject matter of the meeting;
    (4) Whether the meeting is to be open or closed; and
    (5) The name and business telephone number of the offical designated 
by the CSB to respond to requests for information about the meeting.
    (b) The one week advance notice required by paragraph (a) of this 
section may be reduced only if:
    (1) A majority of all Members determines by recorded vote that CSB 
business requires that such meeting be scheduled in less than seven 
days; and
    (2) The public announcement required by paragraph (a) of this 
section is made at the earliest practicable time.
    (c) Immediately following each public announcement required by this 
section, or by Sec.  1603.10, the CSB shall submit a notice of public 
announcement for publication in the Federal Register.



Sec.  1603.10  Changes following public announcement.

    (a) The time or place of a meeting may be changed following the 
public announcement only if the CSB publicly announces such change at 
the earliest practicable time. Members need not approve such change.
    (b) A meeting may be cancelled, or the subject matter of a meeting 
or the determination of the Board to open or to close a meeting, or a 
portion thereof, to the public may be changed following public 
announcement only if:
    (1) A majority of all Members determines by recorded vote that CSB 
business so requires and that no earlier announcement of the 
cancellation or change was possible; and
    (2) The CSB publicly announces such cancellation or change and the 
vote of each Member thereon at the earliest practicable time.
    (c) The deletion of any subject matter announced for a meeting is 
not a change requiring the approval of the Board under paragraph (b) of 
this section.



Sec.  1603.11  Transcripts, recordings, or minutes of closed meetings.

    (a) Along with the General Counsel's certification referred to in 
Sec.  1603.8(d), the CSB shall maintain a complete transcript or 
electronic recording adequate to record fully the proceedings of each 
meeting, or a portion thereof, closed to the public. The CSB may 
maintain a set of minutes in lieu of such transcript or recording for 
meetings closed pursuant to Sec.  1603.7(i). Such minutes shall fully 
and clearly describe all matters discussed and shall provide a full and 
accurate summary of any actions taken, and the reasons therefor, 
including a description of each of the views expressed on any item and 
the record of any rollcall vote. All documents considered in connection 
with any actions shall be identified in such minutes.
    (b) The CSB shall maintain a complete verbatim copy of the 
transcript, a complete copy of the minutes, or a complete electronic 
recording of each meeting, or a portion thereof, closed to the public 
for at least two years after such meeting, or until one year after the 
conclusion of any CSB proceeding with respect to which the meeting, or a 
portion thereof, was held, whichever occurs later.

[[Page 723]]



Sec.  1603.12  Availability of transcripts, recordings, and minutes,
and applicable fees.

    The CSB shall make promptly available to the public the transcript, 
electronic recording, or minutes of the discussion of any item on the 
agenda or of any testimony received at a meeting, except for such item, 
or items, of discussion or testimony as determined by the CSB to contain 
matters which may be withheld under the exemptive provisions of Sec.  
1603.7. Copies of the nonexempt portions of the transcript or minutes, 
or transcription of such recordings disclosing the identity of each 
speaker, shall be furnished to any person at the actual cost of 
transcription or duplication. Requests for transcripts, recordings, or 
minutes shall be made in writing to the General Counsel of the CSB, 2175 
K Street, NW., Suite 400, Washington, DC 20037.



Sec.  1603.13  Report to Congress.

    The CSB General Counsel shall annually report to the Congress 
regarding the Board's compliance with the Government in the Sunshine 
Act, including a tabulation of the total number of open meetings, the 
total number of closed meetings, the reasons for closing such meetings 
and a description of any litigation brought against the Board pursuant 
to the Government in the Sunshine Act, including any cost assessed 
against the Board in such litigation (whether or not paid by the Board).



Sec.  1603.14  Severability.

    If any provision of this part or the application of such provision 
to any person or circumstances, is held invalid, the remainder of this 
part or the application of such provision to persons or circumstances 
other than those as to which it is held invalid, shall not be affected 
thereby.



PART 1604_REPORTING OF ACCIDENTAL RELEASES--Table of Contents



Sec.
1604.1 Purpose.
1604.2 Definitions.
1604.3 Reporting an accidental release.
1604.4 Information required in an accidental release report.
1604.5 Failure to report an accidental release.
1604.6 Public availability of accidental release records.

    Authority: 42 U.S.C. 7412(r)(6)(C)(iii); 42 U.S.C. 7412(r)(6)(N).

    Source: 85 FR 10094, Feb. 21, 2020, unless otherwise noted.



Sec.  1604.1  Purpose.

    The enabling legislation of the Chemical Safety and Hazard 
Investigation Board (CSB) provides that the CSB shall establish by 
regulation requirements binding on persons for reporting accidental 
releases into the ambient air subject to the Board's investigative 
jurisdiction. 42 U.S.C. 7412(r)(6)(C)(iii). This part establishes the 
rule required by the enabling legislation. The purpose of this part is 
to require prompt notification of any accidental release within the 
CSB's investigatory jurisdiction.



Sec.  1604.2  Definitions.

    As used in this part, the following definitions apply:
    Accidental release means an unanticipated emission of a regulated 
substance or other extremely hazardous substance into the ambient air 
from a stationary source.
    Ambient air means any portion of the atmosphere inside or outside a 
stationary source.
    Extremely hazardous substance means any substance which may cause 
death, serious injury, or substantial property damage, including but not 
limited to, any ``regulated substance'' at or below any threshold 
quantity set by the Environmental Protection Agency (EPA) Administrator 
under 42 U.S.C. 7412(r)(5).
    General public means any person except for:
    (1) Workers, employees, or contractors working for (or on behalf of) 
the owner or operator of a stationary source from which an accidental 
release has occurred; and
    (2) Any person acting in the capacity of an emergency responder to 
an accidental release from a stationary source.
    Inpatient hospitalization means a formal admission to the inpatient 
service of a hospital or clinic for care.

[[Page 724]]

    Owner or operator means any person or entity who owns, leases, 
operates, controls, or supervises a stationary source.
    Property damage means damage to or the destruction of tangible 
public or private property, including loss of use of that property.
    Regulated substance means any substance listed pursuant to the 
authority of 42 U.S.C. 7412(r)(3).
    Serious injury means any injury or illness that results in death or 
inpatient hospitalization.
    Stationary source means any buildings, structures, equipment, 
installations, or substance-emitting stationary activities which belong 
to the same industrial group, which are located on one or more 
contiguous properties, which are under the control of the same person 
(or persons under common control), and from which an accidental release 
may occur.
    Substantial property damage means estimated property damage at or 
outside the stationary source equal to or greater than $1,000,000.



Sec.  1604.3  Reporting an accidental release.

    (a) The owner or operator of a stationary source must report in 
accordance with paragraph (b) or (c) of this section, any accidental 
release resulting in a fatality, serious injury, or substantial property 
damage.
    (b) If the owner or operator has submitted a report to the National 
Response Center (NRC) pursuant to 40 CFR 302.6, the CSB reporting 
requirement may be satisfied by submitting the NRC identification number 
to the CSB within 30 minutes of submitting a report to the NRC.
    (c) If the owner or operator has not submitted a report to the NRC 
and notified the CSB under paragraph (b) of this section, the owner/
operator must submit a report directly to the CSB within eight hours of 
the accidental release and must include the required information listed 
in Sec.  1604.4. A report may be made by email to: [email protected], or by 
telephone at 202-261-7600.
    (d) For the purpose of efficiency, multiple owner/operators may 
agree in advance or at the time of release to a single, consolidated 
report on behalf of one or more parties who are responsible for 
reporting an accidental release from a stationary source. However, any 
consolidated report must include all pertinent information required 
under Sec.  1604.4.
    (e) Notwithstanding paragraphs (a) through (d) of this section, an 
owner or operator of a stationary source, without penalty, may revise 
and/or update information reported to the NRC or CSB by sending a 
notification with revisions by email to: [email protected], or by 
correspondence to: Chemical Safety Board (CSB) 1750 Pennsylvania Ave. 
NW, Suite 910, Washington, DC 20006, within 30 days following the 
submission of a report to the NRC or CSB. If applicable, the 
notification must reference the original NRC identification number. No 
update or revisions should be sent to the NRC. In addition to the 
opportunity to revise and/or update information within 30 days, an owner 
or operator may also submit a revised report to the Board within 60 
additional days if the submitter explains why the revised report could 
not have been submitted within the first 30 days.



Sec.  1604.4  Information required in an accidental release report.

    The report required under Sec.  1604.3(c) must include the following 
information regarding an accidental release as applicable:
    (a) The name of, and contact information for, the owner/operator;
    (b) The name of, and contact information for, the person making the 
report;
    (c) The location information and facility identifier;
    (d) The approximate time of the accidental release;
    (e) A brief description of the accidental release;
    (f) An indication whether one or more of the following has occurred:
    (1) Fire;
    (2) Explosion;
    (3) Death;
    (4) Serious injury; or
    (5) Property damage;
    (g) The name of the material(s) involved in the accidental release, 
the Chemical Abstract Service (CAS) number(s), or other appropriate 
identifiers;

[[Page 725]]

    (h) If known, the amount of the release;
    (i) If known, the number of fatalities;
    (j) If known, the number of serious injuries;
    (k) Estimated property damage at or outside the stationary source; 
and
    (l) Whether the accidental release has resulted in an evacuation 
order impacting members of the general public and others, and, if known:
    (1) The number of persons evacuated;
    (2) Approximate radius of the evacuation zone; and
    (3) The type of person subject to the evacuation order (i.e., 
employees, members of the general public, or both).



Sec.  1604.5  Failure to report an accidental release.

    (a) It is unlawful for any person to fail to make reports required 
under this part, and suspected violations of this part will be forwarded 
to the Administrator of the EPA for appropriate enforcement action.
    (b) Violation of this part is subject to enforcement pursuant to the 
authorities of 42 U.S.C. 7413 and 42 U.S.C. 7414, which may include--
    (1) Administrative penalties;
    (2) Civil action; or
    (3) Criminal action.



Sec.  1604.6  Public availability of accidental release records.

    Accidental release records collected by the CSB under this part may 
be obtained by making a request in accordance with 40 CFR part 1601, the 
CSB's procedures for the disclosure of records under the Freedom of 
Information Act. The CSB will process requests, and if appropriate, 
disclose such records, in accordance with 40 CFR part 1601 and relevant 
Federal information disclosure laws.



PART 1610_ADMINISTRATIVE INVESTIGATIONS--Table of Contents



Sec.
1610.1 Representation of witnesses in investigations.
1610.2 Repeated attorney misconduct, sanctions, hearings.
1610.3 Sequestration of witnesses and exclusion of Counsel.
1610.4 Deposition Transcripts.

    Authority: 42 U.S.C. 7412(r)(6)(C)(i), 7412(r)(6)(L), 7412(r)(6)(N).
    Section 1610.4 also issued under 5 U.S.C. 555.

    Source: 66 FR 1050, Jan. 5, 2001, unless otherwise noted.



Sec.  1610.1  Representation of witnesses in investigations.

    (a) Witnesses who are compelled to appear. Witnesses who are 
compelled to appear for a deposition (i.e., by subpoena) are entitled to 
be accompanied, represented, and advised by an attorney as follows:
    (1) Counsel for a witness may advise the witness with respect to any 
question asked where it is claimed that the testimony or other evidence 
sought from a witness is outside the scope of the investigation, or that 
the witness is privileged to refuse to answer a question or to produce 
other evidence. For these allowable objections, the witness or counsel 
for the witness may object on the record to the question or requirement 
and may state briefly and precisely the ground therefor. If the witness 
refuses to answer a question, then counsel may briefly state on the 
record that counsel has advised the witness not to answer the question 
and the legal grounds for such refusal. The witness and his or her 
counsel shall not otherwise object to or refuse to answer any question, 
and they shall not otherwise interrupt the oral examination.
    (2) Any objections made will be treated as continuing objections and 
preserved throughout the further course of the deposition without the 
necessity for repeating them as to any similar line of inquiry. 
Cumulative objections are unnecessary. Repetition of the grounds for any 
objection will not be allowed.
    (3) Counsel for a witness may not, for any purpose or to any extent 
not allowed by paragraphs (a)(1) and (2) of this section, interrupt the 
examination of the witness by making any objections or statements on the 
record.
    (4) Following completion of the examination of a witness, counsel 
for the witness may on the record request the person conducting the 
deposition to permit the witness to clarify any of his or her answers. 
The grant or denial of such request shall be within the sole

[[Page 726]]

discretion of the person conducting the deposition.
    (5) The person conducting the deposition shall take all necessary 
action to regulate the course of the deposition, to avoid delay, and to 
prevent or restrain disorderly, dilatory, obstructionist, or 
contumacious conduct, or contemptuous language. Such person shall, for 
reasons stated on the record, immediately report to the Board any 
instances where an attorney has allegedly refused to comply with his or 
her directions, or has allegedly engaged in disorderly, dilatory, 
obstructionist, or contumacious conduct, or contemptuous language in the 
course of the deposition. The Board may thereupon take such further 
action, if any, as the circumstances warrant, including exclusion of 
that attorney from further participation in the particular 
investigation.
    (b) Voluntary interviews. Witnesses appearing voluntarily do not 
have a right to have an attorney present during questioning. The 
Investigator-in-Charge (IIC), in consultation with the General Counsel, 
may permit a witness to be accompanied by an attorney or non-attorney 
representative. If so accompanied, the role of the attorney or non-
attorney representative is limited to raising objections to questions 
that are outside the scope of the investigation and to advising the 
witness with respect to any legal privilege such as, for example, under 
the Fifth Amendment to the U. S. Constitution. Attorney and non-attorney 
representatives may not represent more than one witness in each 
investigation in this fashion, absent the consent of the IIC and the 
General Counsel.



Sec.  1610.2  Repeated attorney misconduct, sanctions, hearings.

    (a) If an attorney who has been sanctioned by the Board for 
disorderly, dilatory, obstructionist, or contumacious conduct, or 
contemptuous language in the course of a deposition under Sec.  
1610.1(a)(5) is sanctioned again by the Board in a subsequent deposition 
or investigation, the Board, after offering the attorney an opportunity 
to be heard, may reprimand, censure the attorney, or suspend the 
attorney from further practice before the Board for such period of time 
as the Board deems advisable.
    (b) A reprimand or a censure shall be ordered with grounds stated on 
the record of the proceeding. A suspension shall be in writing, shall 
state the grounds on which it is based, and shall advise the person 
suspended of the right to appeal.
    (c) An attorney suspended pursuant to this section may within ten 
(10) days after issuance of the order file an appeal with the Board. The 
appeal shall be in writing and state concisely, with supporting 
argument, why the appellant believes the order was erroneous, either as 
a matter of fact or law. If necessary for a full and fair consideration 
of the facts, the Board as a whole may conduct further evidentiary 
hearings, or may refer the matter to another presiding officer for 
development of a record. Such presiding officer may be an attorney who 
is a Member of the Board or is employed in the Office of General 
Counsel, or an administrative law judge detailed from another agency 
pursuant to 5 U.S.C. 3344. If the Board refers the matter to a presiding 
officer, unless the Board provides specific directions to the presiding 
officer, that officer shall determine the procedure to be followed and 
who shall present evidence, subject to applicable provisions of law. 
Such hearing shall commence as soon as possible. If no appeal is taken 
of a suspension, or, if the suspension is upheld at the conclusion of 
the appeal, the presiding officer, or the Board, as appropriate, shall 
notify the state bar(s) to which the attorney is admitted. Such 
notification shall include copies of the order of suspension, and, if an 
appeal was taken, briefs of the parties, and the decision of the Board.

[66 FR 17363, Mar. 30, 2001]



Sec.  1610.3  Sequestration of witnesses and exclusion of Counsel.

    (a) All witnesses compelled by subpoena to submit to CSB depositions 
shall be sequestered unless the official conducting the depositions 
permits otherwise.
    (b) Any witness compelled by subpoena to appear at a deposition 
during a CSB investigation may be accompanied, represented, and advised 
by an

[[Page 727]]

attorney in good standing of his or her choice, pursuant to Sec.  
1610.1. However, when the CSB official conducting the investigation 
determines, after consultation with the Office of General Counsel, that 
the CSB has concrete evidence that the presence of an attorney 
representing multiple interests would obstruct and impede the 
investigation or inspection, the CSB official may prohibit that counsel 
from being present during the deposition.
    (c) The deposing official is to provide a witness whose counsel has 
been excluded under paragraph (b) of this section, and the witness' 
counsel, a written statement of the reasons supporting the decision to 
exclude. This statement, which must be provided no later than five 
working days after exclusion, must explain the basis for the counsel's 
exclusion. This statement must also advise the witness of the witness' 
right to appeal the exclusion decision and obtain an automatic stay of 
the effectiveness of the subpoena by filing a motion to quash the 
subpoena with the Board within five days of receipt of this written 
statement.
    (d) Within five days after receipt of the written notification 
required in paragraph (c) of this section, a witness whose counsel has 
been excluded may appeal the exclusion decision by filing a motion to 
quash the subpoena with the Board. The filing of the motion to quash 
will stay the effectiveness of the subpoena pending the Board's decision 
on the motion.
    (e) If a witness' counsel is excluded under paragraph (b) of this 
section, the deposition may, at the witness' request, either proceed 
without counsel or be delayed for a reasonable period of time to permit 
the retention of new counsel. The deposition may also be rescheduled to 
a subsequent date established by the CSB, although the deposition shall 
not be rescheduled by the CSB to a date that precedes the expiration of 
the time provided in paragraph (d) of this section for appeal of the 
exclusion of counsel, unless the witness consents to an earlier date.

[66 FR 17363, Mar. 30, 2001]



Sec.  1610.4  Deposition Transcripts.

    (a) Transcripts of depositions of witnesses compelled by subpoena to 
appear during a Board investigation, shall be recorded solely by an 
official reporter designated by the person conducting the deposition.
    (b) Such a witness, after completing the compelled testimony, may 
file a petition with the Board's General Counsel to procure a copy of 
the official transcript of such testimony. The General Counsel shall 
rule on the petition, and may deny it for good cause. Whether or not 
such a petition is filed, the witness (and his or her attorney), upon 
proper identification, shall have the right to inspect the official 
transcript of the witness' own testimony. If such a petition is denied 
by the General Counsel, he shall inform the petitioner of the right to 
inspect the transcript.
    (c) Good cause for denying a witness' petition to procure a 
transcript of his or her testimony may include, but shall not be limited 
to, the protection of: trade secrets and confidential business 
information contained in the testimony, security-sensitive operational 
and vulnerability information, and the integrity of Board 
investigations.

[68 FR 4393, Jan. 29, 2003]



PART 1611_TESTIMONY BY EMPLOYEES IN LEGAL PROCEEDINGS--Table of Contents



Sec.
1611.1 General.
1611.2 Definitions.
1611.3 Scope of permissible testimony.
1611.4 Manner in which testimony is given in civil litigation.
1611.5 Request for testimony in civil litigation.
1611.6 Testimony of former CSB employees.
1611.7 Testimony by current CSB employees regarding prior activity.
1611.8 Procedure in the event of a subpoena in civil litigation.
1611.9 Testimony in Federal, State, or local criminal investigations and 
          other proceedings.
1611.10 Obtaining CSB investigation reports and supporting information.

    Authority: 5 U.S.C. 301, 42 U.S.C. 7412(r)(6)(G).

    Source: 66 FR 17366, Mar. 30, 2001, unless otherwise noted.

[[Page 728]]



Sec.  1611.1  General.

    (a) This part prescribes policies and procedures regarding the 
testimony of employees of the Chemical Safety and Hazard Investigation 
Board (CSB) in suits or actions for damages and criminal proceedings 
arising out of chemical incidents when such testimony is in an official 
capacity and arises out of or is related to an incident investigation. 
The purpose of this part is to ensure that the time of CSB employees is 
used only for official purposes, to avoid embroiling the CSB in 
controversial issues that are not related to its duties, to avoid 
spending public funds for non-CSB purposes, to preserve the impartiality 
of the CSB, and to prohibit the discovery of opinion testimony.
    (b) This part does not apply to:
    (1) Congressional requests or subpoenas for testimony or records;
    (2) Federal court civil proceedings in which the United States is a 
party;
    (3) Federal administrative proceedings;
    (4) Employees who voluntarily testify, while on their own time or in 
approved leave status, as private citizens as to facts or events that 
are not related to the official business of the CSB. The employee must 
state for the record that the testimony represents the employee's own 
views and is not necessarily the official position of the CSB.
    (c) This part only provides guidance for the internal operations of 
the CSB, and neither creates nor is intended to create any enforceable 
right or benefit against the United States.



Sec.  1611.2  Definitions.

    CSB incident report means the report containing the CSB's 
determinations, including the probable cause of an incident, issued 
either as a narrative report or in a computer format. Pursuant to 42 
U.S.C. 7412(r)(6)(G), no part of the conclusions, findings or 
recommendations of the CSB relating to an accidental release or the 
investigation thereof, may be admitted as evidence or used in any suit 
or action for damages growing out of any matter mentioned in such 
report.
    Employee, for the purpose of this part and part 1612 of this 
chapter, refers to current or former CSB Board Members or employees, 
including student interns, and contractors, contract employees, or 
consultants (and their employees). This definition does not include 
persons who are no longer employed by or under contract to the CSB, and 
who are retained or hired as expert witnesses or agree to testify about 
matters that do not involve their work for the CSB.

[66 FR 17366, Mar. 30, 2001, as amended at 66 FR 23854, May 10, 2001]



Sec.  1611.3  Scope of permissible testimony.

    (a) The statute creating the CSB, 42 U.S.C. 7412(r)(6)(G), precludes 
the use or admission into evidence of CSB investigative reports in any 
suit or action for damages arising from such incidents. This provision 
would be undermined if expert opinion testimony of CSB employees, which 
may be reflected in the views of the CSB expressed in its reports, were 
admitted in evidence or used in litigation arising out of an incident. 
The CSB relies heavily upon its investigators' opinions in its 
deliberations. Furthermore, the use of CSB employees as experts to give 
opinion testimony would impose a significant administrative burden on 
the CSB's investigative staff.
    (b) For the reasons stated in paragraph (a) of this section and 
Sec.  1611.1, CSB employees may only testify as to the factual 
information they obtained during the course of an investigation. 
However, they shall decline to testify regarding matters beyond the 
scope of their investigation, and they shall not give any expert or 
opinion testimony.
    (c) CSB employees may testify about the firsthand information they 
obtained during an investigation that is not reasonably available 
elsewhere, including their own factual observations. Consistent with the 
principles cited in Sec.  1611.1 and this section, current CSB employees 
are not authorized to testify regarding other employee's observations or 
reports, or other types of CSB documents, including but not limited to 
safety recommendations, safety studies, safety proposals, safety 
accomplishments, reports labeled studies, and analysis reports, as they 
contain staff analysis and/or CSB conclusions.

[[Page 729]]

    (d) Consistent with 42 U.S.C. 7412(r)(6)(G), a CSB employee may not 
use the CSB's investigation report for any purpose during his testimony.
    (e) No employee may testify in any matter absent advance approval by 
the General Counsel as provided in this part.



Sec.  1611.4  Manner in which testimony is given in civil litigation.

    (a) Testimony of CSB employees with unique, firsthand information 
may be made available for use in civil actions or civil suits for 
damages arising out of incidents through depositions or written 
interrogatories. CSB employees are not permitted to appear and testify 
in court in such actions.
    (b) Normally, depositions will be taken and interrogatories answered 
at the CSB's headquarters in Washington, DC, and at a time arranged with 
the employee reasonably fixed to avoid substantial interference with the 
performance of his or her duties.
    (c) CSB employees are authorized to testify only once in connection 
with any investigation they have made of an incident. Consequently, when 
more than one civil lawsuit arises as a result of an incident, it shall 
be the duty of counsel seeking the employee's deposition to ascertain 
the identity of all parties to the multiple lawsuits and their counsel, 
and to advise them of the fact that a deposition has been granted, so 
that all interested parties may be afforded the opportunity to 
participate therein.
    (d) Upon completion of the deposition of a CSB employee, the 
original of the transcript will be provided to the deponent for 
signature and correction, which the CSB does not waive. A copy of the 
transcript of the testimony and any videotape shall be furnished, at the 
expense of the party requesting the deposition, to the CSB's General 
Counsel at Washington, DC headquarters for the CSB's files.
    (e) If CSB employees are required to travel to testify, under the 
relevant substantive and procedural laws and regulations the party 
requesting the testimony must pay for the costs, including travel 
expenses. Costs must be paid by check or money order payable to the 
Chemical Safety and Hazard Investigation Board.



Sec.  1611.5  Request for testimony in civil litigation.

    (a) A written request for testimony by deposition or interrogatories 
of a CSB employee relating to an incident shall be addressed to the 
General Counsel, who may approve or deny the request consistent with 
this part. Such request shall set forth the title of the civil case, the 
court, the date and place of the incident, the reasons for desiring the 
testimony, and a showing that the information desired is not reasonably 
available from other sources.
    (b) Where testimony is sought in connection with civil litigation, 
the General Counsel shall not approve it until the CSB's investigation 
report is issued.
    (c) The General Counsel shall attach to the approval of any 
deposition such reasonable conditions as may be deemed appropriate in 
order that the testimony will be consistent with Sec.  1611.1, will be 
limited to the matters delineated in Sec.  1611.3, will not interfere 
with the performance of the duties of the employee as set forth in Sec.  
1611.4, and will otherwise conform to the policies of this part.
    (d) A subpoena shall not be served upon a CSB employee in connection 
with the taking of a deposition in civil litigation.



Sec.  1611.6  Testimony of former CSB employees.

    (a) It is not necessary to request CSB approval for testimony of a 
former CSB employee, nor is such testimony limited to depositions. 
However, the scope of permissible testimony continues to be constrained 
by all the limitations set forth in Sec.  1611.3 and Sec.  1611.4.
    (b) Any former employee who is served with a subpoena to appear and 
testify in connection with civil litigation that relates to his or her 
work with the CSB, shall immediately notify the CSB General Counsel and 
provide all information requested by the General Counsel.

[66 FR 17366, Mar. 30, 2001, as amended at 66 FR 23854, May 10, 2001]

[[Page 730]]



Sec.  1611.7  Testimony by current CSB employees regarding prior activity.

    Any testimony regarding any incident within the CSB's jurisdiction, 
or any expert testimony arising from employment prior to CSB service is 
prohibited absent approval by the General Counsel. Approval shall only 
be given if testimony will not violate Sec.  1611.1 and Sec.  1611.3, 
and is subject to whatever conditions the General Counsel finds 
necessary to promote the purposes of this part as set forth in Sec.  
1611.1 and Sec.  1611.3.



Sec.  1611.8  Procedure in the event of a subpoena in civil litigation.

    (a) If the CSB employee has received a subpoena to appear and 
testify in connection with civil litigation, a request for his 
deposition shall not be approved until the subpoena has been withdrawn.
    (b) Upon receipt of a subpoena, the employee shall immediately 
notify the General Counsel and provide all information requested by the 
General Counsel.
    (c) The General Counsel shall determine the course of action to be 
taken and will so advise the employee.



Sec.  1611.9  Testimony in Federal, State, or local criminal
investigations and other proceedings.

    (a) As with civil litigation, the CSB prefers that testimony be 
taken by deposition if court rules permit, and that testimony await the 
issuance of the investigation report. The CSB recognizes, however, that 
in the case of coroner's inquests and grand jury proceedings this may 
not be possible. The CSB encourages those seeking testimony of CSB 
employees to contact the General Counsel as soon as such testimony is 
being considered. Whenever the intent to seek such testimony is 
communicated to the employee, he shall immediately notify the General 
Counsel.
    (b) In any case, CSB employees are prohibited from testifying in any 
civil, criminal, or other matter, either in person or by deposition or 
interrogatories, absent advance approval of the General Counsel.
    (c) If permission to testify by deposition or in person is granted, 
testimony shall be limited as set forth in Sec.  1611.3. Only factual 
testimony is authorized; no expert or opinion testimony shall be given.



Sec.  1611.10  Obtaining CSB investigation reports and
supporting information.

    It is the responsibility of the individual requesting testimony to 
obtain desired documents. There are a number of ways to obtain CSB 
investigation reports, and accompanying investigation docket files. The 
rules at part 1612 of this chapter explain CSB procedures for production 
of records in legal proceedings, and the CSB's Freedom of Information 
Act rules at part 1601 of this chapter explain CSB procedures for 
producing documents more generally. See also the information available 
on the CSB web site, at www.csb.gov. You may also call the CSB Office of 
General Counsel, at (202) 261-7600. Documents will not be supplied by 
witnesses at depositions, nor will copying services be provided by 
deponents.



PART 1612_PRODUCTION OF RECORDS IN LEGAL PROCEEDINGS--Table of Contents



Sec.
1612.1 Purpose and scope.
1612.2 Applicability.
1612.3 Published reports and material contained in the public incident 
          investigation dockets.
1612.4 Requests for authentication or certification of records.
1612.5 Other material.

    Authority: 5 U.S.C. 301, 42 U.S.C. 7412(r)(6)(G).

    Source: 66 FR 17366, Mar. 30, 2001, unless otherwise noted.



Sec.  1612.1  Purpose and scope.

    (a) This part sets forth procedures to be followed when requesting 
material for use in legal proceedings (including administrative 
proceedings) in which the Chemical Safety and Hazard Investigation Board 
(CSB) is not a party, and procedures to be followed by the employee upon 
receipt of a subpoena, order, or other demand (collectively referred to 
here as a demand) for such material by a court or other competent 
authority or by a private litigant. Material, as used in this part, 
means any

[[Page 731]]

type of physical or documentary evidence, including but not limited to 
paper documents, electronic media, videotapes, audiotapes, etc.
    (b) The purposes of this part are to:
    (1) Conserve the time of employees for conducting official business;
    (2) Minimize the possibility of involving the CSB in controversial 
issues not related to its mission;
    (3) Maintain the impartiality of the CSB among private litigants;
    (4) Avoid spending the time and money of the United States for 
private purposes; and
    (5) To protect confidential, sensitive information, and the 
deliberative processes of the CSB.



Sec.  1612.2  Applicability.

    This part applies to requests to produce material concerning 
information acquired in the course of performing official duties or 
because of the employee's official status. Specifically, this part 
applies to requests for: material contained in CSB files; and any 
information or material acquired by an employee of the CSB in the 
performance of official duties or as a result of the employee's status. 
Two sets of procedures are here established, dependent on the type of 
material sought. Rules governing requests for employee testimony, as 
opposed to material production, can be found at part 1611 of this 
chapter. Document production shall not accompany employee testimony, 
absent compliance with this part and General Counsel approval.



Sec.  1612.3  Published reports and material contained in 
the public incident investigation dockets.

    (a) Demands for published investigation reports should be directed 
to the Office of Congressional and Public Affairs, U.S. Chemical Safety 
and Hazard Investigation Board, 2175 K Street, NW, Suite 400, 
Washington, DC 20037. Demands for material contained in the CSB's 
official public docket files of its incident investigations shall be 
submitted, in writing, to CSB Records Officer, U.S. Chemical Safety and 
Hazard Investigation Board, 2175 K Street, NW, Suite 400, Washington, DC 
20037. For information regarding the types of documents routinely issued 
by the CSB, see part 1601 of this chapter.
    (b) No subpoena shall be issued to obtain materials subject to this 
section, and any subpoena issued shall be required to be withdrawn prior 
to release of the requested information. Payment of reproduction fees 
may be required in advance.



Sec.  1612.4  Requests for authentication or certification of records.

    The CSB may authenticate or certify records to facilitate their use 
as evidence. Requests for certified copies should be made to the General 
Counsel at least 30 days before the date they will be needed. The CSB 
may charge a certification fee of $5.00 per document.



Sec.  1612.5  Other material.

    (a) Production prohibited unless approved. Except in the case of the 
material referenced in Sec.  1612.3, no employee or former employee of 
the CSB shall, in response to a demand of a private litigant, court, or 
other authority, produce any material contained in the files of the CSB 
(whether or not agency records under 5 U.S.C. 552) or produce any 
material acquired as part of the performance of the person's official 
duties or because of the person's official status, without the prior 
written approval of the General Counsel.
    (b) Procedures to be followed for the production of material under 
this section. (1) All demands for material shall be submitted to the 
General Counsel at CSB headquarters, 2175 K Street, NW., Suite 400, 
Washington, DC 20037. If an employee receives a demand, he shall forward 
it immediately to the General Counsel.
    (2) Each demand must contain an affidavit by the party seeking the 
material or his attorney setting forth the material sought and its 
relevance to the proceeding, and containing a certification, with 
support, that the information is not available from other sources, 
including CSB materials described in Sec.  1612.3 and part 1601 of this 
chapter.
    (3) In the absence of General Counsel approval of a demand, the 
employee is not authorized to comply with the demand.

[[Page 732]]

    (4) The General Counsel shall advise the requester of approval or 
denial of the demand, and may attach whatever conditions to approval 
considered appropriate or necessary to promote the purposes of this 
part. The General Counsel may also permit exceptions to any requirement 
in this part when necessary to prevent a miscarriage of justice, or when 
the exception is in the best interests of the CSB and/or the United 
States.

                       PARTS 1613	1619 [RESERVED]



PART 1620_ADMINISTRATIVE CLAIMS ARISING UNDER THE 
FEDERAL TORT CLAIMS ACT--Table of Contents



Sec.
1620.1 Purpose and scope of regulations.
1620.2 Administrative claim; when presented.
1620.3 Administrative claim; who may file.
1620.4 Investigations.
1620.5 Administrative claim; evidence and information to be submitted.
1620.6 Authority to adjust, determine, compromise, and settle.
1620.7 Limitations on authority.
1620.8 Referral to Department of Justice.
1620.9 Final denial of claim.
1620.10 Action on approved claim.

    Authority: 28 U.S.C. 2672; 42 U.S.C. 7412(r)(6)(N); 28 CFR 14.11.

    Source: 69 FR 55513, Sept. 15, 2004, unless otherwise noted.



Sec.  1620.1  Purpose and scope of regulations.

    The regulations in this part apply only to administrative claims 
presented or filed with the Chemical Safety and Hazard Investigation 
Board (CSB), under the Federal Tort Claims Act (FTCA), 28 U.S.C. 
1346(b), 2401(b), 2671-2680, as amended, for money damages against the 
United States for damage to or loss of property, personal injury, death, 
or other damages caused by the negligent or wrongful act or omission of 
an officer or employee of CSB while acting within the scope of his or 
her office or employment, but only under circumstances where the United 
States, if a private person, would be liable to the claimant in 
accordance with the law of the place where the act or omission occurred.



Sec.  1620.2  Administrative claim; when presented.

    (a) For purposes of the provisions of 28 U.S.C. 2401(b), 2672, and 
2675, a claim is deemed to have been presented when the CSB receives 
from a claimant, and/or his or her authorized agent, attorney, or other 
legal representative, an executed Standard Form 95 (Claim for Damage, 
Injury or Death), or other written notification of an incident, 
accompanied by a claim for money damages stating a sum certain (a 
specific dollar amount) for specified damage to or loss of property, 
personal injury, death, or other compensable damages alleged to have 
occurred as a result of the incident. A claimant must present a claim 
within 2 years of the date of accrual of the claim. The date of accrual 
generally is determined to be the time of death, injury, or other 
alleged damages, or if the alleged damages are not immediately apparent, 
when the claimant discovered (or reasonably should have discovered) the 
alleged damages and its cause, though the actual date of accrual will 
always depend on the facts of each case. Claimants should be advised 
that mailing a claim by the 2-year time limit is not sufficient if the 
CSB does not receive the claim through the mail by that date. 
Additionally, claimants should be advised that a claim is not considered 
presented by the CSB until the CSB receives all information requested in 
this paragraph. Incomplete claims will be returned to the claimant.
    (b) All claims filed under the FTCA as a result of the alleged 
negligence or wrongful act or omission of the CSB or its employees must 
be mailed or delivered to the Office of the General Counsel, 2175 K 
Street NW., Suite 650, Washington, DC 20037.
    (c) The FTCA requires that a claim must be presented to the Federal 
agency whose activities gave rise to the claim. A claim that should have 
been presented to CSB, but was mistakenly addressed to or filed with 
another Federal agency, is presented to the CSB, as required by 28 
U.S.C. 2401(b), as of the date the claim is received by the CSB. When a 
claim is mistakenly presented to the CSB, the CSB will transfer the 
claim to the appropriate Federal agency, if ascertainable, and advise 
the

[[Page 733]]

claimant of the transfer, or return the claim to the claimant if the 
appropriate Federal agency cannot be determined.
    (d) A claimant whose claim arises from an incident involving the CSB 
and one or more other Federal agencies will identify each agency to 
which the claim has been submitted at the time the claim is presented to 
the CSB. The CSB will contact all other affected Federal agencies in 
order to designate a single agency that will investigate and decide the 
merits of the claim. In the event a designation cannot be agreed upon by 
the affected agencies, the Department of Justice will be consulted and 
that agency will designate a specific agency to investigate and 
determine the merits of the claim. The designated agency will then 
notify the claimant that all future correspondence concerning the claim 
must be directed to the designated Federal agency. All involved Federal 
agencies may agree to conduct their own administrative reviews and to 
coordinate the results, or to have the investigation conducted solely by 
the designated Federal agency. However, in any event, the designated 
agency will be responsible for the final determination of the claim.
    (e) A claim presented in compliance with paragraph (a) of this 
section may be amended by the claimant at any time prior to final agency 
action or prior to the exercise of the claimant's option under 28 U.S.C. 
2675(a). Amendments must be in writing and signed by the claimant or his 
or her authorized agent, attorney, or other legal representative. Upon 
the timely filing of an amendment to a pending claim, the CSB will have 
an additional 6 months in which to investigate the claim and to make a 
final disposition of the claim as amended. A claimant's option under 28 
U.S.C. 2675(a) will not accrue until 6 months after the filing of an 
amendment.



Sec.  1620.3  Administrative claim; who may file.

    (a) A claim for damage to or loss of property may be presented by 
the owner of the property, or his or her authorized agent, attorney, or 
other legal representative.
    (b) A claim for personal injury may be presented by the injured 
person, or his or her authorized agent, attorney or other legal 
representative.
    (c) A claim based on death may be presented by the executor or 
administrator of the decedent's estate, or by any other person legally 
entitled to assert a claim under the applicable State law, provided that 
the basis for the representation is documented in writing.
    (d) A claim for loss totally compensated by an insurer with the 
rights to subrogate may be presented by the insurer. A claim for loss 
partially compensated by an insurer with the rights to subrogate may be 
presented by the insurer or the insured individually as their respective 
interests appear, or jointly. When an insurer presents a claim asserting 
the rights to subrogate the insurer must present appropriate evidence 
that it has the rights to subrogate.
    (e) A claim presented by an agent or legal representative must be 
presented in the name of the claimant, be signed by the agent, attorney, 
or other legal representative, show the title or legal capacity of the 
person signing, and be accompanied by evidence of his or her authority 
to present a claim on behalf of the claimant as agent, attorney, 
executor, administrator, parent, guardian, conservator, or other legal 
representative.



Sec.  1620.4  Investigations.

    CSB may investigate, or may request any other Federal agency to 
investigate, a claim filed under this part.



Sec.  1620.5  Administrative claim; evidence and information
to be submitted.

    (a) Death. In support of a claim based on death, the claimant may be 
required to submit the following evidence or information:
    (1) An authenticated death certificate or other competent evidence 
showing cause of death, date of death, and age of the decedent.
    (2) Decedent's employment or occupation at time of death, including 
his or her monthly or yearly salary or earnings (if any), and the 
duration of his or her last employment or occupation.

[[Page 734]]

    (3) Full names, addresses, birth date, kinship and marital status of 
the decedent's survivors, including identification of those survivors 
who were dependent on support provided by the decedent at the time of 
death.
    (4) Degree of support afforded by the decedent to each survivor 
dependent on him or her for support at the time of death.
    (5) Decedent's general physical and mental condition before death.
    (6) Itemized bills for medical and burial expenses incurred by 
reason of the incident causing death, or itemized receipts of payment 
for such expenses.
    (7) If damages for pain and suffering before death are claimed, a 
physician's detailed statement specifying the injuries suffered, 
duration of pain and suffering, any drugs administered for pain, and the 
decedent's physical condition in the interval between injuries and 
death.
    (8) True and correct copies of relevant medical treatment records, 
laboratory and other tests, including X-Rays, MRI, CT scans and other 
objective evidence of medical evaluation and diagnosis, treatment of 
injury/illness, and prognosis, if any had been made.
    (9) Any other evidence or information that may have a bearing on 
either the responsibility of the United States for the death or the 
amount of damages claimed.
    (b) Personal injury. In support of a claim for personal injury, 
including pain and suffering, the claimant may be required to submit the 
following evidence or information:
    (1) A written report by the attending physician or dentist setting 
forth the nature and extent of the injury, nature and extent of 
treatment, any degree of temporary or permanent disability, the 
prognosis, period of hospitalization, and any diminished earning 
capacity. If damages for pain and suffering are claimed, a physician's 
detailed statement specifying the duration of pain and suffering, a 
listing of drugs administered for pain, and the claimant's general 
physical condition.
    (2) True and correct copies of relevant medical treatment records, 
laboratory and other tests including X-Rays, MRI, CT scans and other 
objective evidence of medical evaluation and diagnosis, treatment 
injury/illness and prognosis.
    (3) The claimant may be required to submit to a physical or mental 
examination by a physician employed by CSB or another Federal agency. On 
written request, CSB will make available to the claimant a copy of the 
report of the examining physician employed by the United States, 
provided the claimant has furnished CSB with the information noted in 
paragraphs (b)(1) and (b)(2) of this section. In addition, the claimant 
must have made or agrees to make available to CSB all other physicians' 
reports previously or thereafter made of the physical or mental 
condition that is subject matter of his or her claim.
    (4) Itemized bills for medical, dental, and hospital expenses 
incurred, and/or itemized receipts of payment for such expenses.
    (5) If the prognosis reveals the necessity for future treatment, a 
statement of the expected treatment and the expected expense for such 
treatment.
    (6) If a claim is made for loss of time from employment, a written 
statement from his or her employer showing actual time lost from 
employment, whether he or she is a full-time or part-time employee, and 
wages or salary actually lost.
    (7) If a claim is made for loss of income and the claimant is self-
employed, documentary evidence showing the amount of earnings actually 
lost.
    (8) Any other evidence or information that may have a bearing on 
either the responsibility of the United States for the personal injury 
or the damages claimed.
    (c) Property damage. In support of a claim for damage to or loss of 
property, real or personal, the claimant may be required to submit the 
following evidence or information:
    (1) Proof of ownership of the property.
    (2) A detailed statement of the amount claimed with respect to each 
item of property.
    (3) An itemized receipt of payment for necessary repairs or itemized 
written estimates of the cost of such repairs.

[[Page 735]]

    (4) A statement listing date of purchase, purchase price, and 
salvage value.
    (5) Photographs or video footage documenting the damage, including 
photographs showing the condition of the property at issue both before 
and after the alleged negligence or wrongful act or omission.
    (6) Any other evidence or information that may have a bearing on 
either the responsibility of the United States for the damage to or loss 
of property or the damages claimed.



Sec.  1620.6  Authority to adjust, determine, compromise, and settle.

    The General Counsel of CSB, or his or her designee, is delegated 
authority to consider, ascertain, adjust, determine, compromise and 
settle claims under the provision of 28 U.S.C. 2672, and this part. The 
General Counsel, in his or her discretion, has the authority to further 
delegate the responsibility for adjudicating, considering, adjusting, 
compromising and settling any claim submitted under the provision of 28 
U.S.C. 2672, and this part, that is based on the alleged negligence or 
wrongful act or omission of a CSB employee acting in the scope of his or 
her employment. However, in any case, any offer of compromise or 
settlement in excess of $5,000 exercised by the CSB Chairperson or any 
other lawful designee can only be made after a legal review is conducted 
by an attorney within the CSB Office of General Counsel.



Sec.  1620.7  Limitations on authority.

    (a) An award, compromise, or settlement of a claim under 28 U.S.C. 
2672, and this part, in excess of $25,000 can be made only with the 
prior written approval of the CSB General Counsel and Chairperson, after 
consultation and approval by the Department of Justice. For purposes of 
this paragraph a principal claim and any derivative or subrogated claim 
will be treated as a single claim.
    (b) An administrative claim may be adjusted, determined, compromised 
or settled under this part only after consultation with the Department 
of Justice when, in the opinion of the General Counsel of CSB, or his or 
her designee:
    (1) A new precedent or a new point of law is involved; or
    (2) A question of policy is or may be involved; or
    (3) The United States is or may be entitled to indemnity or 
contribution from a third party and CSB is unable to adjust the third 
party claim; or
    (4) The compromise of a particular claim, as a practical matter, 
will or may control the disposition of a related claim in which the 
amount to be paid may exceed $25,000.
    (c) An administrative claim may be adjusted, determined, compromised 
or settled under 28 U.S.C. 2672 and this part only after consultation 
with the Department of Justice when CSB is informed or is otherwise 
aware that the United States or an employee, agent or contractor of the 
United States is involved in litigation based on a claim arising out of 
the same incident or transaction.



Sec.  1620.8  Referral to Department of Justice.

    When Department of Justice approval or consultation is required, or 
the advice of the Department of Justice is otherwise to be requested, 
under this regulation, the written referral or request will be 
transmitted to the Department of Justice by the General Counsel of CSB, 
or his or her designee.



Sec.  1620.9  Final denial of claim.

    Final denial of an administrative claim must be in writing and sent 
to the claimant, his or her agent, attorney, or other legal 
representative by certified or registered mail. The notification of 
final denial may include a statement of the reasons for the denial. 
However, it must include a statement that, if the claimant is 
dissatisfied with the CSB action, he or she may file suit in an 
appropriate United States District Court not later than 6 months after 
the date of mailing of the notifications, along with the admonition that 
failure to file within this 6 month timeframe could result in the suit 
being time-barred by the controlling statute of limitations. In the 
event that a claimant does not hear from the CSB after 6 months have 
passed from the date that the claim was presented, a claimant should 
consider the claim

[[Page 736]]

denied and, if desired, should proceed with filing a civil action in the 
appropriate U.S. District Court.



Sec.  1620.10  Action on approved claim.

    (a) Payment of a claim approved under this part is contingent on 
claimant's execution of a Standard Form 95 (Claim for Damage, Injury or 
Death); a claims settlement agreement; and a Standard Form 1145 (Voucher 
for Payment), as well as any other forms as may be required. When a 
claimant is represented by an attorney, the Voucher for Payment will 
designate both the claimant and his or her attorney as payees, and the 
check will be delivered to the attorney, whose address is to appear on 
the Voucher for payment.
    (b) Acceptance by the claimant, his or her agent, attorney, or legal 
representative, of an award, compromise or settlement made under 28 
U.S.C. 2672 or 28 U.S.C. 2677 is final and conclusive on the claimant, 
his or her agent, attorney, or legal representative, and any other 
person on whose behalf or for whose benefit the claim has been 
presented, and constitutes a complete release of any and all claims 
against the United States and against any employee of the Federal 
Government whose act(s) or omission(s) gave rise to the claim, by reason 
of the same subject matter. To that end, as noted above, the claimant, 
as well as any agent, attorney or other legal representative that 
represented the claimant during any phase of the process (if applicable) 
must execute a settlement agreement with the CSB prior to payment of any 
funds.

                       PARTS 1621	1699 [RESERVED]

[[Page 737]]



CHAPTER VII--ENVIRONMENTAL PROTECTION AGENCY AND DEPARTMENT OF DEFENSE; 
  UNIFORM NATIONAL DISCHARGE STANDARDS FOR VESSELS OF THE ARMED FORCES




  --------------------------------------------------------------------
Part                                                                Page
1700            Uniform National Discharge Standards for 
                    vessels of the Armed Forces.............         739
1701-1799

 [Reserved]

[[Page 739]]



PART 1700_UNIFORM NATIONAL DISCHARGE STANDARDS 
FOR VESSELS OF THE ARMED FORCES--Table of Contents



                             Subpart A_Scope

Sec.
1700.1 Applicability.
1700.2 Effect.
1700.3 Definitions.

                   Subpart B_Discharge Determinations

1700.4 Discharges requiring control.
1700.5 Discharges not requiring control.

                       Subpart C_Effect on States

1700.6 Effect on State and local statutes and regulations.

                           No-Discharge Zones

1700.7 No-discharge zones.
1700.8 Discharges for which no-discharge zones can be established.
1700.9 No-discharge zones by State prohibition.
1700.10 No-discharge zones by EPA prohibition.

                        State Petition for Review

1700.11 State petition for review of determinations or standards.
1700.12 Petition requirements.
1700.13 Petition decisions.

 Subpart D_Marine Pollution Control Device (MPCD) Performance Standards

1700.14 Aqueous film-forming foam.
1700.15 Catapult water brake tank & post-launch retraction exhaust.
1700.16 Chain locker effluent.
1700.17-1700.18 [Reserved]
1700.19 Controllable pitch propeller hydraulic fluid.
1700.20 Deck runoff.
1700.21 [Reserved]
1700.22 Distillation and reverse osmosis brine.
1700.23 Elevator pit effluent.
1700.24 Firemain systems.
1700.25 Gas turbine water wash.
1700.26 Graywater.
1700.27 Hull coating leachate.
1700.28 Motor gasoline and compensating discharge.
1700.29 Non-oily machinery wastewater.
1700.30 Photographic laboratory drains.
1700.31 Seawater cooling overboard discharge.
1700.32 Seawater piping biofouling prevention.
1700.33 Small boat engine wet exhaust.
1700.34 Sonar dome discharge.
1700.35 Submarine bilgewater.
1700.36 Surface vessel bilgewater/oil-water separator effluent.
1700.37 Underwater ship husbandry.
1700.38 Welldeck discharges.
1700.39 Exceptions.
1700.40 Commingling of discharges.
1700.41 Records.
1700.42 Non-compliance reports.

    Authority: 33 U.S.C. 1322, 1361.

    Source: 64 FR 25134, May 10, 1999, unless otherwise noted.



                             Subpart A_Scope



Sec.  1700.1  Applicability.

    (a) This part applies to the owners and operators of Armed Forces 
vessels, except where the Secretary of Defense finds that compliance 
with this part is not in the interest of the national security of the 
United States. This part does not apply to vessels while they are under 
construction, vessels in drydock, amphibious vehicles, or vessels under 
the jurisdiction of the Department of Transportation other than those of 
the Coast Guard.
    (b) This part also applies to States and political subdivisions of 
States.



Sec.  1700.2  Effect.

    (a) This part identifies those discharges, other than sewage, 
incidental to the normal operation of vessels of the Armed Forces that 
require control within the navigable waters of the United States, 
including the territorial seas and the waters of the contiguous zone, 
and those discharges that do not require control. Discharges requiring 
control are identified in Sec.  1700.4. Discharges not requiring control 
are identified in Sec.  1700.5. Federal standards of performance for 
each required Marine Pollution Control Device are listed in Sec. Sec.  
1700.14 through 1700.38. Federal standards of performance apply to all 
vessels, whether existing or new, and regardless of vessel class, type, 
or size, unless otherwise expressly provided in Sec. Sec.  1700.14 
through 1700.38.
    (b) This part prohibits States and their political subdivisions from 
adopting or enforcing State or local statutes or regulations controlling 
the discharges from Armed Forces vessels listed in Sec. Sec.  1700.4 and 
1700.5 according to the timing provisions in Sec.  1700.6, except

[[Page 740]]

to establish a no-discharge zone by State prohibition in accordance with 
Sec.  1700.9, or to apply for a no-discharge zone by EPA prohibition in 
accordance with Sec.  1700.10. This part also provides a mechanism for 
States to petition the Administrator and the Secretary to review a 
determination of whether a discharge requires control, or to review a 
Federal standard of performance for a Marine Pollution Control Device, 
in accordance with Sec. Sec.  1700.11 through 1700.13.

[64 FR 25134, May 10, 1999, as amended at 82 FR 3182, Jan. 11, 2017]



Sec.  1700.3  Definitions.

    Administrator means the Administrator of the United States 
Environmental Protection Agency or that person's authorized 
representative.
    Armed Forces vessel means a vessel owned or operated by the United 
States Department of Defense or the United States Coast Guard, other 
than vessels that are time or voyage chartered by the Armed Forces, 
vessels of the U.S. Army Corps of Engineers, or vessels that are 
memorials or museums.
    Bioaccumulative means the opposite of not bioaccumulative.
    Biodegradable means the following for purposes of the standards:
    (1) Regarding environmentally acceptable lubricants and greases, 
biodegradable means lubricant formulations that contain at least 90% 
(weight in weight concentration or w/w) or grease formulations that 
contain at least 75% (w/w) of a constituent substance or constituent 
substances (only stated substances present above 0.10% must be assessed) 
that each demonstrate either the removal of at least 70% of dissolved 
organic carbon, production of at least 60% of the theoretical carbon 
dioxide, or consumption of at least 60% of the theoretical oxygen demand 
within 28 days. Test methods include: Organization for Economic Co-
operation and Development Test Guidelines 301 A-F, 306, and 310, ASTM 
5864, ASTM D-7373, OCSPP Harmonized Guideline 835.3110, and 
International Organization for Standardization 14593:1999. For lubricant 
formulations, the 10% (w/w) of the formulation that need not meet the 
above biodegradability requirements, up to 5% (w/w) may be non-
biodegradable, but not bioaccumulative, while the remaining 5-10% must 
be inherently biodegradable. For grease formulations, the 25% (w/w) of 
the formulation that need not meet the above biodegradability 
requirement, the constituent substances may be either inherently 
biodegradable or non-biodegradable, but may not be bioaccumulative. Test 
methods to demonstrate inherent biodegradability include: OECD Test 
Guidelines 302C (70% biodegradation after 28 days) or OECD 
Test Guidelines 301 A-F (20% but <60% biodegradation after 28 
days).
    (2) Regarding cleaning products, biodegradable means products that 
demonstrate either the removal of at least 70% of dissolved organic 
carbon, production of at least 60% of the theoretical carbon dioxide, or 
consumption of at least 60% of the theoretical oxygen demand within 28 
days. Test methods include: Organization for Economic Cooperation and 
Development Test Guidelines 301 A-F, 306, and 310, and International 
Organization for Standardization 14593:1999.
    (3) Regarding biocidal substances, biodegradable means a compound or 
mixture that yields 60% of theoretical maximum carbon dioxide and 
demonstrate a removal of at least 70% of dissolved organic carbon within 
28 days as described in EPA 712-C-98-075 (OPPTS 835.3100 Aerobic Aquatic 
Biodegradation).
    Discharge incidental to the normal operation of a vessel means a 
discharge, including, but not limited to: graywater, bilgewater, cooling 
water, weather deck runoff, ballast water, oil water separator effluent, 
and any other pollutant discharge from the operation of a marine 
propulsion system, shipboard maneuvering system, crew habitability 
system, or installed major equipment, such as an aircraft carrier 
elevator or a catapult, or from a protective, preservative, or 
absorptive application to the hull of a vessel; and a discharge in 
connection with the testing, maintenance, and repair of any of the 
aforementioned systems whenever the vessel is waterborne, including 
pierside. A discharge incidental to normal operation does not include:
    (1) Sewage;
    (2) A discharge of rubbish, trash, or garbage;

[[Page 741]]

    (3) A discharge of air emissions resulting from the operation of a 
vessel propulsion system, motor driven equipment, or incinerator;
    (4) A discharge that requires a National Pollutant Discharge 
Elimination System (NPDES) permit under the Clean Water Act; or
    (5) A discharge containing source, special nuclear, or byproduct 
materials regulated by the Atomic Energy Act.
    Environmental Protection Agency, abbreviated EPA, means the United 
States Environmental Protection Agency.
    Environmentally acceptable lubricants means lubricants that are 
biodegradable, minimally-toxic, and not bioaccumulative as defined in 
this subpart. The following labeling programs and organizations meet the 
definition of being environmentally acceptable lubricants: Blue Angel, 
European Ecolabel, Nordic Swan, the Swedish Standards SS 155434 and 
155470, Safer Choice, and the Convention for the Protection of the 
Marine Environment of the North-East Atlantic (OSPAR) requirements.
    Federally-protected waters means waters within 12 miles of the 
United States that are also part of any of the following:
    (1) Marine sanctuaries designated under the National Marine 
Sanctuaries Act (16 U.S.C. 1431 et seq.) or Marine National Monuments 
designated under the Antiquities Act of 1906;
    (2) A unit of the National Wildlife Refuge System, including Wetland 
Management Districts, Waterfowl Production Areas, National Game 
Preserves, Wildlife Management Areas, and National Fish and Wildlife 
Refuges;
    (3) National Wilderness Areas; and
    (4) Any component designated under the National Wild and Scenic 
Rivers System.
    Great Lakes means waters of the United States extending to the 
international maritime boundary with Canada in Lake Ontario, Lake Erie, 
Lake Huron (including Lake St. Clair), Lake Michigan, and Lake Superior, 
and the connecting channels (Saint Marys River, Saint Clair River, 
Detroit River, Niagara River, and Saint Lawrence River to the 
international maritime boundary with Canada).
    Hazardous material means any hazardous material as defined in 49 CFR 
171.8.
    Marine Pollution Control Device, abbreviated MPCD, means any 
equipment or management practice installed or used on an Armed Forces 
vessel that is designed to receive, retain, treat, control, or discharge 
a discharge incidental to the normal operation of a vessel, and that is 
determined by the Administrator and Secretary to be the most effective 
equipment or management practice to reduce the environmental impacts of 
the discharge consistent with the considerations in Clean Water Act 
section 312(n)(2)(B).
    Minimally-toxic means a substance must pass either OECD 201, 202, 
and 203 for acute toxicity testing, or OECD 210 and 211 for chronic 
toxicity testing. For purposes of the standards, equivalent toxicity 
data for marine species, including methods ISO/DIS 10253 for algae, ISO 
TC147/SC5/W62 for crustacean, and OSPAR 2005 for fish, may be 
substituted for OECD 201, 202, and 203. If a substance is evaluated for 
the formulation and main constituents, the LC50 of fluids must be at 
least 100 mg/L and the LC50 of greases, two-stroke oils, and all other 
total loss lubricants must be at least 1000 mg/L. If a substance is 
evaluated for each constituent substance, rather than the complete 
formulation and main compounds, then constituents comprising less than 
20% of fluids can have an LC50 between 10-100 mg/L or a no-observed-
effect concentration (NOEC) between 1-10 mg/L, constituents comprising 
less than 5% of fluids can have an LC50 between 1-10 mg/L or a NOEC 
between 0.1-1 mg/L, and constituents comprising less than 1% of fluids, 
can have an LC50 less than 1 mg/L or a NOEC between 0-0.1 mg/L.
    Minimally-toxic soaps, cleaners, and detergents means any substance 
or mixture of substances which has an acute aquatic toxicity value 
(LC50) corresponding to a concentration greater than 10 parts per 
million (ppm) and does not produce byproducts with an acute aquatic 
toxicity value (LC50) corresponding to a concentration less than 10 ppm. 
Minimally-toxic soaps, cleaners, and detergents typically contain little 
to no nonylphenols.

[[Page 742]]

    No-discharge zone means an area of specified waters established 
pursuant to this regulation into which one or more specified discharges 
incidental to the normal operation of Armed Forces vessels, whether 
treated or untreated, are prohibited.
    Not bioaccumulative means any of the following: The partition 
coefficient in the marine environment is log Kow <3 or 7 
using test methods OECD 117 and 107; molecular mass 800 
Daltons; molecular diameter 1.5 nanometer; bioconcentration 
factor (BCF) or bioaccumulation factor (BAF) is <100 L/kg, using OECD 
305, OCSPP 850.1710 or OCSPP 850.1730, or a field-measured BAF; or 
polymer with molecular weight (MW) fraction below 1,000 g/mol is <1%.
    Person in charge (PIC) means the single individual named master of 
the vessel or placed in charge of the vessel, by the U.S. Department of 
Defense or by the Department in which the U.S. Coast Guard is operating, 
as appropriate, and who is responsible for the operation, manning, 
victualing, and supplying of the vessel of the Armed Forces. Examples of 
a PIC include, but are not limited to:
    (1) A Commanding Officer, Officer in Charge, or senior commissioned 
officer on board the vessel;
    (2) A civilian, military, or U.S. Coast Guard person assigned to a 
shore command or activity that has been designated as the PIC for one or 
more vessels, such as a group of boats or craft;
    (3) A Tugmaster, Craftmaster, Coxswain, or other senior enlisted 
person onboard the vessel;
    (4) A licensed civilian mariner onboard a Military Sealift Command 
vessel; or
    (5) A contracted commercial person at a shore installation that is 
not part of the Armed Forces but as identified by the U.S. Department of 
Defense or the Department in which the U.S. Coast Guard is operating.
    Phosphate-free soaps, cleaners, and detergents means any substance 
or mixture of substances which contain, by weight, 0.5% or less of 
phosphates or derivatives of phosphates.
    Secretary means the Secretary of the United States Department of 
Defense or that person's authorized representative.
    Toxic materials means any toxic pollutant identified in 40 CFR 
401.15.
    State means a state, the District of Columbia, the Commonwealth of 
Puerto Rico, the Virgin Islands, Guam, American Samoa, the Commonwealth 
of the Northern Mariana Islands, and the Trust Territory of the Pacific 
Islands.
    United States includes the States, the District of Columbia, the 
Commonwealth of Puerto Rico, the Virgin Islands, Guam, American Samoa, 
the Canal Zone, and the Trust Territory of the Pacific Islands.
    Vessel includes every description of watercraft or other artificial 
contrivance used, or capable of being used, as a means of transportation 
on navigable waters of the United States or waters of the contiguous 
zone, but does not include amphibious vehicles.
    Waters subject to UNDS means the navigable waters of the United 
States, including the territorial seas and the waters of the contiguous 
zone, as these terms are defined in the Clean Water Act (33 U.S.C. 
1362).

[64 FR 25134, May 10, 1999, as amended at 82 FR 3182, Jan. 11, 2017; 85 
FR 43475, July 17, 2020]



                   Subpart B_Discharge Determinations



Sec.  1700.4  Discharges requiring control.

    For the following discharges incidental to the normal operation of 
Armed Forces vessels, the Administrator and the Secretary have 
determined that it is reasonable and practicable to require use of a 
Marine Pollution Control Device for at least one class of vessel to 
mitigate adverse impacts on the marine environment:
    (a) Aqueous Film-Forming Foam: the firefighting foam and seawater 
mixture discharged during training, testing, or maintenance operations.
    (b) Catapult Water Brake Tank & Post-Launch Retraction Exhaust: the 
oily water skimmed from the water tank used to stop the forward motion 
of an aircraft carrier catapult, and the condensed steam discharged when 
the catapult is retracted.

[[Page 743]]

    (c) Chain Locker Effluent: the accumulated precipitation and 
seawater that is emptied from the compartment used to store the vessel's 
anchor chain.
    (d) Clean Ballast: the seawater taken into, and discharged from, 
dedicated ballast tanks to maintain the stability of the vessel and to 
adjust the buoyancy of submarines.
    (e) Compensated Fuel Ballast: the seawater taken into, and 
discharged from, ballast tanks designed to hold both ballast water and 
fuel to maintain the stability of the vessel.
    (f) Controllable Pitch Propeller Hydraulic Fluid: the hydraulic 
fluid that discharges into the surrounding seawater from propeller seals 
as part of normal operation, and the hydraulic fluid released during 
routine maintenance of the propellers.
    (g) Deck Runoff: the precipitation, washdowns, and seawater falling 
on the weather deck of a vessel and discharged overboard through deck 
openings.
    (h) Dirty Ballast: the seawater taken into, and discharged from, 
empty fuel tanks to maintain the stability of the vessel.
    (i) Distillation and Reverse Osmosis Brine: the concentrated 
seawater (brine) produced as a byproduct of the processes used to 
generate freshwater from seawater.
    (j) Elevator Pit Effluent: the liquid that accumulates in, and is 
discharged from, the sumps of elevator wells on vessels.
    (k) Firemain Systems: the seawater pumped through the firemain 
system for firemain testing, maintenance, and training, and to supply 
water for the operation of certain vessel systems.
    (l) Gas Turbine Water Wash: the water released from washing gas 
turbine components.
    (m) Graywater: galley, bath, and shower water, as well as wastewater 
from lavatory sinks, laundry, interior deck drains, water fountains, and 
shop sinks.
    (n) Hull Coating Leachate: the constituents that leach, dissolve, 
ablate, or erode from the paint on the hull into the surrounding 
seawater.
    (o) Motor Gasoline and Compensating Discharge: the seawater taken 
into, and discharged from, motor gasoline tanks to eliminate free space 
where vapors could accumulate.
    (p) Non-Oily machinery wastewater: the combined wastewater from the 
operation of distilling plants, water chillers, valve packings, water 
piping, low- and high-pressure air compressors, and propulsion engine 
jacket coolers.
    (q) Photographic Laboratory Drains: the laboratory wastewater 
resulting from processing of photographic film.
    (r) Seawater Cooling Overboard Discharge: the discharge of seawater 
from a dedicated system that provides noncontact cooling water for other 
vessel systems.
    (s) Seawater Piping Biofouling Prevention: the discharge of seawater 
containing additives used to prevent the growth and attachment of 
biofouling organisms in dedicated seawater cooling systems on selected 
vessels.
    (t) Small Boat Engine Wet Exhaust: the seawater that is mixed and 
discharged with small boat propulsion engine exhaust to cool the exhaust 
and quiet the engine.
    (u) Sonar Dome Discharge: the leaching of antifoulant materials into 
the surrounding seawater and the release of seawater or freshwater 
retained within the sonar dome.
    (v) Submarine Bilgewater: the wastewater from a variety of sources 
that accumulates in the lowest part of the submarine (i.e., bilge).
    (w) Surface Vessel Bilgewater/Oil-Water Separator Effluent: the 
wastewater from a variety of sources that accumulates in the lowest part 
of the vessel (the bilge), and the effluent produced when the wastewater 
is processed by an oil water separator.
    (x) Underwater Ship Husbandry: the materials discharged during the 
inspection, maintenance, cleaning, and repair of hulls performed while 
the vessel is waterborne.
    (y) Welldeck Discharges: the water that accumulates from seawater 
flooding of the docking well (welldeck) of a vessel used to transport, 
load, and unload amphibious vessels, and from maintenance and freshwater 
washings of the welldeck and equipment and vessels stored in the 
welldeck.

[[Page 744]]



Sec.  1700.5  Discharges not requiring control.

    For the following discharges incidental to the normal operation of 
Armed Forces vessels, the Administrator and the Secretary have 
determined that it is not reasonable or practicable to require use of a 
Marine Pollution Control Device to mitigate adverse impacts on the 
marine environment:
    (a) Boiler Blowdown: the water and steam discharged when a steam 
boiler is blown down, or when a steam safety valve is tested.
    (b) Catapult Wet Accumulator Discharge: the water discharged from a 
catapult wet accumulator, which stores a steam/water mixture for 
launching aircraft from an aircraft carrier.
    (c) Cathodic Protection: the constituents released into surrounding 
water from sacrificial anode or impressed current cathodic hull 
corrosion protection systems.
    (d) Freshwater Lay-up: the potable water that is discharged from the 
seawater cooling system while the vessel is in port, and the cooling 
system is in lay-up mode (a standby mode where seawater in the system is 
replaced with potable water for corrosion protection).
    (e) Mine Countermeasures Equipment Lubrication: the constituents 
released into the surrounding seawater by erosion or dissolution from 
lubricated mine countermeasures equipment when the equipment is deployed 
and towed.
    (f) Portable Damage Control Drain Pump Discharge: the seawater 
pumped through the portable damage control drain pump and discharged 
overboard during testing, maintenance, and training activities.
    (g) Portable Damage Control Drain Pump Wet Exhaust: the seawater 
mixed and discharged with portable damage control drain pump exhaust to 
cool the exhaust and quiet the engine.
    (h) Refrigeration and Air Conditioning Condensate: the drainage of 
condensed moisture from air conditioning units, refrigerators, freezers, 
and refrigerated spaces.
    (i) Rudder Bearing Lubrication: the oil or grease released by the 
erosion or dissolution from lubricated bearings that support the rudder 
and allow it to turn freely.
    (j) Steam Condensate: the condensed steam discharged from a vessel 
in port, where the steam originates from port facilities.
    (k) Stern Tube Seals and Underwater Bearing Lubrication: the 
seawater pumped through stern tube seals and underwater bearings to 
lubricate and cool them during normal operation.
    (l) Submarine Acoustic Countermeasures Launcher Discharge: the 
seawater that is mixed with acoustic countermeasure device propulsion 
gas following a countermeasure launch that is then exchanged with 
surrounding seawater, or partially drained when the launch assembly is 
removed from the submarine for maintenance.
    (m) Submarine Emergency Diesel Engine Wet Exhaust: the seawater that 
is mixed and discharged with submarine emergency diesel engine exhaust 
to cool the exhaust and quiet the engine.
    (n) Submarine Outboard Equipment Grease and External Hydraulics: the 
grease released into the surrounding seawater by erosion or dissolution 
from submarine equipment exposed to seawater.



                       Subpart C_Effect on States



Sec.  1700.6  Effect on State and local statutes and regulations.

    (a) After the effective date of a final rule determining that it is 
not reasonable and practicable to require use of a Marine Pollution 
Control Device regarding a particular discharge incidental to the normal 
operation of an Armed Forces vessel, States or political subdivisions of 
States may not adopt or enforce any State or local statute or 
regulation, including issuance or enforcement of permits under the 
National Pollutant Discharge Elimination System, controlling that 
discharge, except that States may establish a no-discharge zone by State 
prohibition (as provided in Sec.  1700.9), or apply for a no-discharge 
zone by EPA prohibition (as provided in Sec.  1700.10).
    (b)(1) After the effective date of a final rule determining that it 
is reasonable and practicable to require use of a

[[Page 745]]

Marine Pollution Control Device regarding a particular discharge 
incidental to the normal operation of an Armed Forces vessel, States may 
apply for a no-discharge zone by EPA prohibition (as provided in Sec.  
1700.10) for that discharge.
    (2) After the effective date of a final rule promulgated by the 
Secretary governing the design, construction, installation, and use of a 
Marine Pollution Control Device for a discharge listed in Sec.  1700.4, 
States or political subdivisions of States may not adopt or enforce any 
State or local statute or regulation, including issuance or enforcement 
of permits under the National Pollutant Discharge Elimination System, 
controlling that discharge except that States may establish a no-
discharge zone by State prohibition (as provided in Sec.  1700.9), or 
apply for a no-discharge zone by EPA prohibition (as provided in Sec.  
1700.10).
    (c) The Governor of any State may submit a petition requesting that 
the Administrator and Secretary review a determination of whether a 
Marine Pollution Control Device is required for any discharge listed in 
Sec.  1700.4 or Sec.  1700.5, or review a Federal standard of 
performance for a Marine Pollution Control Device.

                           No-Discharge Zones



Sec.  1700.7  No-discharge zones.

    For this part, a no-discharge zone is a waterbody, or portion 
thereof, where one or more discharges incidental to the normal operation 
of Armed Forces vessels, whether treated or not, are prohibited. A no-
discharge zone is established either by State prohibition using the 
procedures in Sec.  1700.9, or by EPA prohibition, upon application of a 
State, using the procedures in Sec.  1700.10.



Sec.  1700.8  Discharges for which no-discharge zones can be established.

    (a) A no-discharge zone may be established by State prohibition for 
any discharge listed in Sec.  1700.4 or Sec.  1700.5 following the 
procedures in Sec.  1700.9. A no-discharge zone established by a State 
using these procedures may apply only to those discharges that have been 
preempted from other State or local regulation pursuant to Sec.  1700.6.
    (b) A no-discharge zone may be established by EPA prohibition for 
any discharge listed in Sec.  1700.4 or Sec.  1700.5 following the 
procedures in Sec.  1700.10.



Sec.  1700.9  No-discharge zones by State prohibition.

    (a) A State seeking to establish a no-discharge zone by State 
prohibition must send to the Administrator the following information:
    (1) The discharge from Sec.  1700.4 or Sec.  1700.5 to be prohibited 
within the no-discharge zone.
    (2) A detailed description of the waterbody, or portions thereof, to 
be included in the prohibition. The description must include a map, 
preferably a USGS topographic quadrant map, clearly marking the zone 
boundaries by latitude and longitude.
    (3) A determination that the protection and enhancement of the 
waters described in paragraph (a)(2) of this section require greater 
environmental protection than provided by existing Federal standards.
    (4) A complete description of the facilities reasonably available 
for collecting the discharge including:
    (i) A map showing their location(s) and a written location 
description.
    (ii) A demonstration that the facilities have the capacity and 
capability to provide safe and sanitary removal of the volume of 
discharge being prohibited in terms of both vessel berthing and 
discharge reception.
    (iii) The schedule of operating hours of the facilities.
    (iv) The draft requirements of the vessel(s) that will be required 
to use the facilities and the available water depth at the facilities.
    (v) Information showing that handling of the discharge at the 
facilities is in conformance with Federal law.
    (5) Information on whether vessels other than those of the Armed 
Forces are subject to the same type of prohibition. If the State is not 
applying the prohibition to all vessels in the area, the State must 
demonstrate the technical or environmental basis for applying the 
prohibition only to Armed Forces vessels. The following information must 
be included in the technical or environmental basis for treating Armed 
Forces vessels differently:

[[Page 746]]

    (i) An analysis showing the relative contributions of the discharge 
from Armed Forces and non-Armed Forces vessels.
    (ii) A description of State efforts to control the discharge from 
non-Armed Forces vessels.
    (b) The information provided under paragraph (a) of this section 
must be sufficient to enable EPA to make the two determinations listed 
below. Prior to making these determinations, EPA will consult with the 
Secretary on the adequacy of the facilities and the operational impact 
of any prohibition on Armed Forces vessels.
    (1) Adequate facilities for the safe and sanitary removal of the 
discharge are reasonably available for the specified waters.
    (2) The prohibition will not have the effect of discriminating 
against vessels of the Armed Forces by reason of the ownership or 
operation by the Federal Government, or the military function, of the 
vessels.
    (c) EPA will notify the State in writing of the result of the 
determinations under paragraph (b) of this section, and will provide a 
written explanation of any negative determinations. A no-discharge zone 
established by State prohibition will not go into effect until EPA 
determines that the conditions of paragraph (b) of this section have 
been met.



Sec.  1700.10  No-discharge zones by EPA prohibition.

    (a) A State requesting EPA to establish a no-discharge zone must 
send to the Administrator an application containing the following 
information:
    (1) The discharge from Sec.  1700.4 or Sec.  1700.5 to be prohibited 
within the no-discharge zone.
    (2) A detailed description of the waterbody, or portions thereof, to 
be included in the prohibition. The description must include a map, 
preferably a USGS topographic quadrant map, clearly marking the zone 
boundaries by latitude and longitude.
    (3) A technical analysis showing why protection and enhancement of 
the waters described in paragraph (a)(2) of this section require a 
prohibition of the discharge. The analysis must provide specific 
information on why the discharge adversely impacts the zone and how 
prohibition will protect the zone. In addition, the analysis should 
characterize any sensitive areas, such as aquatic sanctuaries, fish-
spawning and nursery areas, pristine areas, areas not meeting water 
quality standards, drinking water intakes, and recreational areas.
    (4) A complete description of the facilities reasonably available 
for collecting the discharge including:
    (i) A map showing their location(s) and a written location 
description.
    (ii) A demonstration that the facilities have the capacity and 
capability to provide safe and sanitary removal of the volume of 
discharge being prohibited in terms of both vessel berthing and 
discharge reception.
    (iii) The schedule of operating hours of the facilities.
    (iv) The draft requirements of the vessel(s) that will be required 
to use the facilities and the available water depth at the facilities.
    (v) Information showing that handling of the discharge at the 
facilities is in conformance with Federal law.
    (5) Information on whether vessels other than those of the Armed 
Forces are subject to the same type of prohibition. If the State is not 
applying a prohibition to other vessels in the area, the State must 
demonstrate the technical or environmental basis for applying a 
prohibition only to Armed Forces vessels. The following information must 
be included in the technical or environmental basis for treating Armed 
Forces vessels differently:
    (i) An analysis showing the relative contributions of the discharge 
from Armed Forces and non-Armed Forces vessels.
    (ii) A description of State efforts to control the discharge from 
non-Armed Forces vessels.
    (b) The information provided under paragraph (a) of this section 
must be sufficient to enable EPA to make the three determinations listed 
below. Prior to making these determinations, EPA will consult with the 
Secretary on the adequacy of the facilities and the operational impact 
of the prohibition on Armed Forces vessels.
    (1) The protection and enhancement of the specified waters require a 
prohibition of the discharge.

[[Page 747]]

    (2) Adequate facilities for the safe and sanitary removal of the 
discharge are reasonably available for the specified waters.
    (3) The prohibition will not have the effect of discriminating 
against vessels of the Armed Forces by reason of the ownership or 
operation by the Federal Government, or the military function, or the 
vessels.
    (c) If the three conditions in paragraph (b) of this section are 
met, EPA will by regulation establish the no-discharge zone. If the 
conditions in paragraphs (b) (1) and (3) of this section are met, but 
the condition in paragraph (b)(2) of this section is not met, EPA may 
establish the no-discharge zone if it determines that the significance 
of the waters and the potential impact of the discharge are of 
sufficient magnitude to warrant any resulting constraints on Armed 
Forces vessels.
    (d) EPA will notify the State of its decision on the no-discharge 
zone application in writing. If EPA approves the no-discharge zone 
application, EPA will by regulation establish the no-discharge zone by 
modification to this part. A no-discharge zone established by EPA 
prohibition will not go into effect until the effective date of the 
regulation.

                        State Petition for Review



Sec.  1700.11  State petition for review of determinations or standards.

    The Governor of any State may submit a petition requesting that the 
Administrator and Secretary review a determination of whether a Marine 
Pollution Control Device is required for any discharge listed in Sec.  
1700.4 or Sec.  1700.5, or review a Federal standard of performance for 
a Marine Pollution Control Device. A State may submit a petition only 
where there is new, significant information not considered previously by 
the Administrator and Secretary.



Sec.  1700.12  Petition requirements.

    A petition for review of a determination or standard must include:
    (a) The discharge from Sec.  1700.4 or Sec.  1700.5 for which a 
change in determination is requested, or the performance standard from 
Sec.  1700.14 for which review is requested.
    (b) The scientific and technical information on which the petition 
is based.
    (c) A detailed explanation of why the State believes that 
consideration of the new information should result in a change to the 
determination or the standard on a nationwide basis, and an explanation 
of how the new information is relevant to one or more of the following 
factors:
    (1) The nature of the discharge.
    (2) The environmental effects of the discharge.
    (3) The practicability of using a Marine Pollution Control Device.
    (4) The effect that installation or use of the Marine Pollution 
Control Device would have on the operation or operational capability of 
the vessel.
    (5) Applicable United States law.
    (6) Applicable international standards.
    (7) The economic costs of the installation and use of the Marine 
Pollution Control Device.



Sec.  1700.13  Petition decisions.

    The Administrator and the Secretary will evaluate the petition and 
grant or deny the petition no later than two years after the date of 
receipt of the petition. If the Administrator and Secretary grant the 
petition, they will undertake rulemaking to amend this part. If the 
Administrator and Secretary deny the petition, they will provide the 
State with a written explanation of why they denied it.



 Subpart D_Marine Pollution Control Device (MPCD) Performance Standards

    Source: 82 3183, Jan. 11, 2017, unless otherwise noted.



Sec.  1700.14  Aqueous film-forming foam.

    (a) For the purposes of this section, regulated aqueous film-forming 
foam (AFFF) refers only to firefighting foam and seawater mixture 
discharged during training, testing, or maintenance operations.
    (b) For all vessels that sail seaward of waters subject to UNDS at 
least once per month, the discharge of AFFF is prohibited.

[[Page 748]]

    (c) For all vessels that do not sail seaward of waters subject to 
UNDS at least once per month:
    (1) The discharge of fluorinated AFFF is prohibited; and
    (2) The discharges of non-fluorinated or alternative foaming agent 
are prohibited in port or in or near federally-protected waters, and 
must occur as far from shore as possible.



Sec.  1700.15  Catapult water brake tank & post-launch
retraction exhaust.

    (a) Discharges of catapult water brake tank effluent are prohibited.
    (b) The number of post-launch retractions must be limited to the 
minimum number required to test and validate the system and conduct 
qualification and operational training.

[85 FR 43475, July 17, 2020]



Sec.  1700.16  Chain locker effluent.

    (a) For all vessels, except submarines, the anchor chain must be 
carefully and thoroughly washed down(i.e., more than a cursory rinse) as 
it is being hauled out of the water to remove sediment and organisms.
    (b) For all vessels, the chain lockers must be cleaned periodically 
to eliminate accumulated sediments and any potential accompanying 
pollutants. The dates of all chain locker inspections must be recorded 
in the ship's log or other vessel recordkeeping documentation.
    (c) For all vessels that sail seaward of waters subject to UNDS at 
least once per month, the rinsing or pumping out of chain lockers is 
prohibited.
    (d) For all vessels that do not sail seaward of waters subject to 
UNDS at least once per month, the rinsing or pumping out of chain 
lockers must occur as far from shore as possible and, if technically 
feasible, the rinsing or pumping out of chain lockers must not occur in 
federally-protected waters.



Sec. Sec.  1700.17-1700.18  [Reserved]



Sec.  1700.19  Controllable pitch propeller hydraulic fluid.

    (a) The protective seals on controllable pitch propellers must be 
maintained to minimize the leaking of hydraulic fluid.
    (b) To the greatest extent practicable, maintenance activities on 
controllable pitch propellers must be conducted when a vessel is in 
drydock. If maintenance and repair activities must occur when the vessel 
is not in drydock, appropriate spill response equipment (e.g., oil 
booms) must be used to contain and clean any oil leakage.
    (c) The discharge of controllable pitch propeller hydraulic fluid 
must not contain oil in quantities that:
    (1) Cause a film or sheen upon or discoloration of the surface of 
the water or adjoining shorelines; or
    (2) Cause a sludge or emulsion to be deposited beneath the surface 
of the water or upon adjoining shorelines; or
    (3) Contain an oil content above 15 ppm as measured by EPA Method 
1664a (as defined in 40 CFR 136.3) or other appropriate method for 
determination of oil content as accepted by the International Maritime 
Organization (IMO) (e.g., ISO Method 9377) or U.S. Coast Guard; or
    (4) Otherwise are harmful to the public health or welfare of the 
United States.

[85 FR 43475, July 17, 2020]



Sec.  1700.20  Deck runoff.

    (a) Flight deck washdowns are prohibited.
    (b) Minimize deck washdowns while in port and in federally-protected 
waters.
    (c) Prior to performing a deck washdown, exposed decks must be broom 
cleaned and on-deck debris, garbage, paint chips, residues, and spills 
must be removed, collected, and disposed of onshore in accordance with 
any applicable solid waste or hazardous substance management and 
disposal requirements.
    (d) If a deck washdown or above water line hull cleaning will result 
in a discharge, it must be conducted with minimally-toxic and phosphate-
free soaps, cleaners, and detergents. The use of soaps that are labeled 
toxic is prohibited. Furthermore, soaps, cleaners, and detergents should 
not be caustic and must be biodegradable. All soaps and cleaners must be 
used as directed by the label.
    (e) Where feasible, machinery on deck must have coamings or drip 
pans,

[[Page 749]]

where necessary, to prevent spills and collect any oily discharge that 
may leak from machinery. The drip pans must be drained to a waste 
container for disposal onshore in accordance with any applicable oil and 
hazardous substance management and disposal requirements. The presence 
of floating solids, visible foam, halogenated phenol compounds, 
dispersants, and surfactants in deck washdowns must be minimized.
    (f) Topside surfaces and other above water line portions of the 
vessel must be well maintained to minimize the discharge of rust (and 
other corrosion by-products), cleaning compounds, paint chips, non-skid 
material fragments, and other materials associated with exterior topside 
surface preservation. Residual paint droplets entering the water must be 
minimized when conducting maintenance painting. The discharge of unused 
paint is prohibited. Paint chips and unused paint residues must be 
collected and disposed of onshore in accordance with any applicable 
solid waste and hazardous substance management and disposal 
requirements.
    (g) When vessels conduct underway fuel replenishment, scuppers must 
be plugged to prevent the discharge of oil. Any oil spilled must be 
cleaned, managed, and disposed of onshore in accordance with any 
applicable oil and hazardous substance management and disposal 
requirements.

[85 FR 43475, July 17, 2020]



Sec.  1700.21  [Reserved]



Sec.  1700.22  Distillation and reverse osmosis brine.

    The discharge of brine from the distillation system and the 
discharge of reverse osmosis reject water are prohibited if they come in 
contact with machinery or industrial equipment (other than distillation 
or reverse osmosis machinery), toxic or hazardous materials, or wastes.



Sec.  1700.23  Elevator pit effluent.

    (a) The direct discharge of elevator pit effluent is prohibited.
    (b) Notwithstanding the prohibition of direct discharges of elevator 
pit effluent overboard, if the elevator pit effluent is commingled with 
any other discharge for the purposes of treatment prior to discharge, 
then under no circumstances may oils, including oily mixtures, be 
discharged from that combined discharge in quantities that:
    (1) Cause a film or sheen upon or discoloration of the surface of 
the water or adjoining shorelines; or
    (2) Cause a sludge or emulsion to be deposited beneath the surface 
of the water or upon adjoining shorelines; or
    (3) Contain an oil content above 15 ppm as measured by EPA Method 
1664a or other appropriate method for determination of oil content as 
accepted by the International Maritime Organization (IMO) (e.g., ISO 
Method 9377) or U.S. Coast Guard; or
    (4) Otherwise are harmful to the public health or welfare of the 
United States.



Sec.  1700.24  Firemain systems.

    (a) Firemain systems may be discharged for testing and inspections 
of the firemain system. To the greatest extent practicable, conduct 
maintenance and training outside of port and as far away from shore as 
possible. Firemain systems may be discharged in port for certification, 
maintenance, and training requirements if the intake comes directly from 
the surrounding waters or potable water supplies and there are no 
additions (e.g., aqueous film-forming foam) to the discharge.
    (b) Firemain systems must not be discharged in federally-protected 
waters except when needed to washdown the anchor chain to comply with 
anchor washdown requirements in Subpart 1700.16.
    (c) Firemain systems may be used for secondary uses if the intake 
comes directly from the surrounding waters or potable water supplies.

[85 FR 43476, July 17, 2020]



Sec.  1700.25  Gas turbine water wash.

    (a) The direct discharge of gas turbine water wash is prohibited.
    (b) To the greatest extent practicable, gas turbine water wash must 
be collected separately and disposed of onshore in accordance with any 
applicable solid waste and hazardous substance management and disposal 
requirements.

[[Page 750]]

    (c) Notwithstanding the prohibition of direct discharges of gas 
turbine water wash overboard, if the gas turbine water wash is 
commingled with any other discharge for the purposes of treatment prior 
to discharge then under no circumstances may oils, including oily 
mixtures be discharged from that combined discharge in quantities that:
    (1) Cause a film or sheen upon or discoloration of the surface of 
the water or adjoining shorelines; or
    (2) Cause a sludge or emulsion to be deposited beneath the surface 
of the water or upon adjoining shorelines; or
    (3) Contain an oil content above 15 ppm as measured by EPA Method 
1664a or other appropriate method for determination of oil content as 
accepted by the International Maritime Organization (IMO) (e.g., ISO 
Method 9377) or U.S. Coast Guard; or
    (4) Otherwise are harmful to the public health or welfare of the 
United States.



Sec.  1700.26  Graywater.

    (a) For discharges from vessels that have the capacity to hold 
graywater:
    (1) Graywater must not be discharged in federally-protected waters 
or the Great Lakes.
    (2) Graywater must not be discharged within one mile of shore if an 
onshore facility is available and disposal at such a facility is 
reasonable and practicable.
    (3) Production and discharge of graywater must be minimized within 
one mile of shore when an onshore facility is either not available or 
use of such a facility is not reasonable and practicable.
    (b) For discharges from vessels that do not have the capacity to 
hold graywater:
    (1) Production and discharge of graywater must be minimized in 
federally-protected waters or the Great Lakes.
    (2) Graywater must not be discharged within one mile of shore if an 
onshore facility is available and disposal at such a facility is 
reasonable and practicable.
    (3) Production and discharge of graywater must be minimized within 
one mile of shore when an onshore facility is either not available or 
use of such a facility is not reasonable and practicable.
    (c) Large quantities of cooking oils (e.g., from a deep fat fryer), 
including animal fats and vegetable oils, must not be added to the 
graywater system. Small quantities of cooking oils (e.g., from pot and 
dish rinsing) must be minimized if added to the graywater system within 
three miles of shore.
    (d) Minimally-toxic soaps, cleaners, and detergents and phosphate-
free soaps, cleaners, and detergents must be used in the galley, 
scullery, and laundry. These soaps, cleaners, and detergents should also 
be free from bioaccumulative compounds and not lead to extreme shifts in 
the receiving water pH. For purposes of this subparagraph, extreme 
shifts means causing the receiving water pH to fall below 6.0 or rise 
above 9.0 as a direct result of the discharge.
    (e) The discharge of graywater must not contain oil in quantities 
that:
    (1) Cause a film or sheen upon or discoloration of the surface of 
the water or adjoining shorelines; or
    (2) Cause a sludge or emulsion to be deposited beneath the surface 
of the water or upon adjoining shorelines; or
    (3) Contain an oil content above 15 ppm as measured by EPA Method 
1664a (as defined at 40 CFR 136.3) or other appropriate method for 
determination of oil content as accepted by the International Maritime 
Organization (IMO) (e.g., ISO Method 9377) or U.S. Coast Guard; or
    (4) Otherwise are harmful to the public health or welfare of the 
United States.

[85 FR 43476, July 17, 2020]



Sec.  1700.27  Hull coating leachate.

    (a) Antifouling hull coatings subject to registration under the 
Federal Insecticide, Fungicide, and Rodenticide Act (FIFRA) (7 U.S.C 136 
et seq.) must be applied, maintained, and removed in a manner consistent 
with requirements on the coatings' FIFRA label.
    (b) Antifouling hull coatings not subject to FIFRA registration 
(i.e., exempt or not produced for sale and distribution in the United 
States) must not contain any biocides or toxic materials banned for use 
in the United States.

[[Page 751]]

This performance standard applies to all vessels, including vessels with 
a hull coating applied outside the United States.
    (c) Antifouling hull coatings must not contain tributyltin (TBT).
    (d) Antifouling hull coatings must not contain any organotin 
compounds when the organotin is used as a biocide. Antifouling hull 
coatings may contain small quantities of organotin compounds other than 
tributyltin (e.g., dibutyltin) when the organotin is acting as a 
chemical catalyst and not present above 2,500 milligrams total tin per 
kilogram of dry paint film. In addition, any antifouling hull coatings 
containing organotin must be designed to not slough or peel from the 
vessel hull.
    (e) Antifouling hull coatings that contain TBT or other organotin 
compounds that are used as a biocide must be removed or an overcoat must 
be applied.
    (f) Incidental amounts of antifouling hull coating discharged after 
contact with other hard surfaces (e.g., moorings) are permissible.
    (g) To the greatest extent practicable, use non-copper based and 
less toxic antifouling hull coatings. To the greatest extent 
practicable, use antifouling hull coatings with the lowest effective 
biocide release rates, rapidly biodegradable components (once separated 
from the hull surface), or use non-biocidal alternatives, such as 
silicone coatings.
    (h) To the greatest extent practicable, avoid use of antifouling 
hull coatings on vessels that are regularly removed from the water and 
unlikely to accumulate hull growth.

[85 FR 43476, July 17, 2020]



Sec.  1700.28  Motor gasoline and compensating discharge.

    (a) The discharge of motor gasoline and compensating effluent must 
not contain oil in quantities that:
    (1) Cause a film or sheen upon or discoloration of the surface of 
the water or adjoining shorelines; or
    (2) Cause a sludge or emulsion to be deposited beneath the surface 
of the water or upon adjoining shorelines; or
    (3) Contain an oil content above 15 ppm as measured by EPA Method 
1664a (as defined at 40 CFR136.3) or other appropriate method for 
determination of oil content as accepted by the International Maritime 
Organization (IMO) (e.g., ISO Method 9377) or U.S. Coast Guard; or
    (4) Otherwise are harmful to the public health or welfare of the 
United States.
    (b) The discharge of motor gasoline and compensating effluent must 
be minimized in port. If an oily sheen is observed, any spill or 
overflow of oil must be cleaned up, recorded, and reported to the 
National Response Center immediately.
    (c) The discharge of motor gasoline and compensating effluent is 
prohibited in federally-protected waters.

[85 FR 43476, July 17, 2020]



Sec.  1700.29  Non-oily machinery wastewater.

    The discharge of non-oily machinery wastewater must not contain any 
additives that are toxic or bioaccumulative in nature, and under no 
circumstances may oils, including oily mixtures, be discharged in 
quantities that:
    (a) Cause a film or sheen upon or discoloration of the surface of 
the water or adjoining shorelines; or
    (b) Cause a sludge or emulsion to be deposited beneath the surface 
of the water or upon adjoining shorelines; or
    (c) Contain an oil content above 15 ppm as measured by EPA Method 
1664a or other appropriate method for determination of oil content as 
accepted by the International Maritime Organization (IMO) (e.g., ISO 
Method 9377) or U.S. Coast Guard; or
    (d) Otherwise are harmful to the public health or welfare of the 
United States.



Sec.  1700.30  Photographic laboratory drains.

    The discharge of photographic laboratory drains is prohibited.



Sec.  1700.31  Seawater cooling overboard discharge.

    (a) For discharges from vessels that are less than 79 feet in 
length:
    (1) To the greatest extent practicable, minimize non-contact engine 
cooling water, hydraulic system cooling water, refrigeration cooling 
water

[[Page 752]]

and other seawater cooling overboard discharges when the vessel is in 
port.
    (2) To reduce the production and discharge of seawater cooling 
overboard discharge, the vessel should use shore based power when in 
port if:
    (i) Shore power is readily available for the vessel from utilities 
or port authorities; and
    (ii) Shore based power supply systems are capable of providing all 
needed electricity required for vessel operations; and
    (iii) The vessel is equipped to connect to shore-based power and 
such systems are compatible with the available shore power.
    (3) Fouling organisms must be removed from seawater piping on a 
regular basis. The discharge of fouling organisms removed during 
cleanings is prohibited.
    (b) For discharges from vessels that are greater than or equal to 79 
feet in length:
    (1) To the greatest extent practicable, minimize non-contact engine 
cooling water, hydraulic system cooling water, refrigeration cooling 
water and other seawater cooling overboard discharges when the vessel is 
in port.
    (2) To reduce the production and discharge of seawater cooling 
overboard discharge, the vessel should use shore based power when in 
port if:
    (i) Shore power is readily available for the vessel from utilities 
or port authorities; and
    (ii) Shore based power supply systems are capable of providing all 
needed electricity required for vessel operations; and
    (iii) The vessel is equipped to connect to shore-based power and 
such systems are compatible with the available shore power.
    (3) Maintenance of all piping and seawater cooling systems must meet 
the requirements of Sec.  1700.32 (Seawater Piping Biofouling 
Prevention). For all vessels, except submarines, fouling organisms 
removed during maintenance must not be discharged.



Sec.  1700.32  Seawater piping biofouling prevention.

    (a) Seawater piping biofouling chemicals subject to registration 
under the Federal Insecticide, Fungicide, and Rodenticide Act (FIFRA) (7 
U.S.C. 136 et seq.) must be used in accordance with the FIFRA label. 
Pesticides or chemicals banned for use in the United States must not be 
discharged.
    (b) To the greatest extent practicable, only the minimum amount of 
biofouling chemicals must be used to keep fouling under control.
    (c) Fouling organisms must be removed from seawater piping on a 
regular basis. For all vessels, except submarines, the discharge of 
fouling organisms removed during cleanings is prohibited.



Sec.  1700.33  Small boat engine wet exhaust.

    (a) For the purposes of this section small boat engine wet exhaust 
discharges refers only to discharges from vessels that are less than 79 
feet in length.
    (b) Vessels generating small boat engine wet exhaust must be 
maintained in good operating order, well-tuned, and functioning 
according to manufacturer specifications, in order to decrease pollutant 
concentrations and volumes in small boat engine wet exhaust.
    (c) To the greatest extent practicable, low sulfur or alternative 
fuels must be used to reduce the concentration of pollutants in 
discharges from small boat engine wet exhaust.
    (d) To the greatest extent practicable, use four-stroke engines 
instead of two-stroke engines for vessels generating small boat engine 
wet exhaust.
    (e) Vessels using two-stroke engines must use environmentally 
acceptable lubricants unless use of such lubricants is technologically 
infeasible. If technologically infeasible, the use and justification for 
the use of a non-environmentally acceptable lubricant must be recorded 
in the vessel recordkeeping documentation.



Sec.  1700.34  Sonar dome discharge.

    (a) The water inside the sonar dome must not be discharged for 
maintenance activities unless the use of a drydock for the maintenance 
activity is not feasible.
    (b) The water inside the sonar dome may be discharged for 
equalization of

[[Page 753]]

pressure between the interior and exterior of the dome.
    (c) A biofouling chemical that is bioaccumulative should not be 
applied to the exterior of a sonar dome when a non-bioaccumulative 
alternative is available.

[85 FR 43476, July 17, 2020]



Sec.  1700.35  Submarine bilgewater.

    The discharge of submarine bilgewater:
    (a) Must not contain oil in quantities that:
    (1) Cause a film or sheen upon or discoloration of the surface of 
the water or adjoining shorelines; or
    (2) Cause a sludge or emulsion to be deposited beneath the surface 
of the water or upon adjoining shorelines; or
    (3) Contain an oil content above 15 parts per million (ppm) as 
measured by EPA Method 1664a (as defined at 40 CFR 136.3) or other 
appropriate method for determination of oil content as accepted by the 
International Maritime Organization (IMO) (e.g., ISO Method 9377) or 
U.S. Coast Guard; or
    (4) Otherwise are harmful to the public health or welfare of the 
United States.
    (b) Must not contain dispersants, detergents, emulsifiers, 
chemicals, or other substances added for the purposes of removing the 
appearance of a visible sheen. This performance standard does not 
prohibit the use of these materials in machinery spaces for the purposes 
of cleaning and maintenance activities associated with vessel equipment 
and structures.
    (c) Must only contain substances that are produced in the normal 
operation of a vessel. Oil solidifiers, flocculants or other additives 
(excluding any dispersants or surfactants) may be used to enhance oil-
water separation during processing in an oil-water separator only if 
such solidifiers, flocculants, or other additives are minimized in the 
discharge and do not alter the chemical makeup of the oils being 
discharged. Solidifiers, flocculants, or other additives must not be 
directly added, or otherwise combined with, the water in the bilge. 
Additionally, the vessel must employ management practices that will 
minimize the leakage of oil and other harmful pollutants into the bilge.
    (d) Must not occur in port if the port has the capability to collect 
and transfer the submarine bilgewater to an onshore facility.
    (e) Must be minimized and, if technologically feasible, discharged 
as far from shore as possible.
    (f) Must be minimized in federally-protected waters.

[85 FR 43477, July 17, 2020]



Sec.  1700.36  Surface vessel bilgewater/oil-water separator effluent.

    (a) All surface vessels must employ management practices that will 
minimize leakage of oil and other harmful pollutants into the bilge.
    (b) Surface vessels equipped with an oil-water separator must not 
discharge bilgewater and must only discharge oil-water separator 
effluent through an oil-content monitor consistent with paragraph (c) of 
this section. All surface vessels greater than 400 gross tons must be 
equipped with an oil-water separator. Surface vessels not equipped with 
an oil-water separator must only discharge bilgewater consistent with 
paragraph (d) of this section.
    (c) The discharge of oil-water separator effluent:
    (1) Must not contain oil in quantities that:
    (i) Cause a film or sheen upon or discoloration of the surface of 
the water or adjoining shorelines; or
    (ii) Cause a sludge or emulsion to be deposited beneath the surface 
of the water or upon adjoining shorelines; or
    (iii) Contain an oil content above 15 ppm as measured by EPA Method 
1664a (as defined at 40 CFR 136.3) or other appropriate method for 
determination of oil content as accepted by the International Maritime 
Organization (IMO) (e.g., ISO Method 9377) or U.S. Coast Guard; or
    (iv) Otherwise are harmful to the public health or welfare of the 
United States.
    (2) Must not contain dispersants, detergents, emulsifiers, 
chemicals, or other substances added for the purposes of removing the 
appearance of a visible sheen. This performance standard does not 
prohibit the use of these materials in machinery spaces for the

[[Page 754]]

purposes of cleaning and maintenance activities associated with vessel 
equipment and structures.
    (3) Must only contain substances that are produced in the normal 
operation of a vessel. Oil solidifiers, flocculants or other additives 
(excluding any dispersants or surfactants) may be used to enhance oil-
water separation during processing in an oil-water separator only if 
such solidifiers, flocculants, or other additives are minimized in the 
discharge and do not alter the chemical make-up of the oils being 
discharged. Solidifiers, flocculants, or other additives must not be 
directly added, or otherwise combined with, the water in the bilge.
    (4) Must not occur in port if the vessel has the capability to 
collect and transfer oil-water separator effluent to an onshore 
facility.
    (5) Must be minimized within one mile of shore.
    (6) Must occur while sailing at speeds greater than six knots, if 
the vessel is underway.
    (7) Must be minimized in federally-protected waters.
    (d) The discharge of bilgewater (i.e., wastewater from the bilge 
that has not been processed through an oil-water separator):
    (1) Must not occur if the vessel has the capability to collect, 
hold, and transfer bilgewater to an onshore facility.
    (2) Notwithstanding the prohibition of the discharge of bilgewater 
from vessels that have the capability to collect, hold, and transfer 
bilgewater to an onshore facility; the discharge of bilgewater:
    (i) Must not contain dispersants, detergents, emulsifiers, 
chemicals, or other substances added for the purposes of removing the 
appearance of a visible sheen. This performance standard does not 
prohibit the use of these materials in machinery spaces for the purposes 
of cleaning and maintenance activities associated with vessel equipment 
and structures.
    (ii) Must only contain substances that are produced in the normal 
operation of a vessel. Routine cleaning and maintenance activities 
associated with vessel equipment and structures are considered to be 
normal operation of a vessel.
    (iii) Must not contain oil in quantities that:
    (A) Cause a film or sheen upon or discoloration of the surface of 
the water or adjoining shorelines; or
    (B) Cause a sludge or emulsion to be deposited beneath the surface 
of the water or upon adjoining shorelines; or
    (C) Contain an oil content above 15 ppm as measured by EPA Method 
1664a (as defined at 40CFR 136.3) or other appropriate method for 
determination of oil content as accepted by the International Maritime 
Organization (IMO) (e.g., ISO Method 9377) or U.S. Coast Guard; or
    (D) Otherwise are harmful to the public health or welfare of the 
United States.
    (iv) Must be suspended immediately if a visible sheen is observed. 
Any spill or overflow of oil or other engine fluids must be cleaned up, 
recorded, and reported to the National Response Center immediately.

[85 FR 43477, July 17, 2020]



Sec.  1700.37  Underwater ship husbandry.

    (a) For discharges from vessels that are less than 79 feet in 
length:
    (1) To the greatest extent practicable, vessel hulls with an 
antifouling hull coating must not be cleaned within 90 days after the 
antifouling coating application.
    (2) Vessel hulls must be inspected, maintained, and cleaned to 
minimize the removal and discharge of antifouling coatings and the 
transport of fouling organisms. To the greatest extent practicable, 
rigorous vessel hull cleanings must take place in drydock or at a land-
based facility where the removed fouling organisms or spent antifouling 
coatings can be disposed of onshore in accordance with any applicable 
solid waste or hazardous substance management and disposal requirements.
    (3) Prior to the transport of the vessel overland from one body of 
water to another, vessel hulls must be inspected for any visible 
attached living organisms. If fouling organisms are found, they must be 
removed and disposed of

[[Page 755]]

onshore in accordance with any applicable solid waste and hazardous 
substance management and disposal requirements.
    (4) Vessel hull cleanings must be conducted in a manner that 
minimizes the release of antifouling hull coatings and fouling 
organisms, including:
    (i) Adhere to any applicable cleaning requirements found on the 
coatings' FIFRA label.
    (ii) Use soft brushes or less abrasive cleaning techniques to the 
greatest extent practicable.
    (iii) Use hard brushes only for the removal of hard growth.
    (iv) Use a vacuum or other collection/control technology, when 
available and feasible. Residues filtered, precipitated, or otherwise 
removed by any vacuum technology must be disposed of onshore in 
accordance with any applicable solid waste and hazardous substance 
management and disposal requirements.
    (b) For discharges from vessels that are greater than or equal to 79 
feet in length:
    (1) To the greatest extent practicable, vessel hulls with an 
antifouling hull coating must not be cleaned within 90 days after the 
antifouling coating application. To the greatest extent practicable, 
vessel hulls with copper-based antifouling coatings must not be cleaned 
within 365 days after coating application.
    (2) Vessel hulls must be inspected, maintained, and cleaned to 
minimize the removal and discharge of antifouling coatings and the 
transport of fouling organisms. To the greatest extent practicable, 
rigorous vessel hull cleanings must take place in drydock or at a land-
based facility where the removed fouling organisms or spent antifouling 
coatings can be disposed of onshore in accordance with any applicable 
solid waste or hazardous substance management and disposal requirements.
    (3) Vessel hull cleanings must be conducted in a manner that 
minimizes the release of antifouling hull coatings and fouling 
organisms, including:
    (i) Adhere to any applicable cleaning requirements found on the 
coatings' FIFRA label.
    (ii) Use soft brushes or less abrasive cleaning techniques to the 
greatest extent practicable.
    (iii) Use hard brushes only for the removal of hard growth.
    (iv) Use a vacuum or other collection/control technology, when 
available and feasible. Residues filtered, precipitated, or otherwise 
removed by any vacuum technology must be disposed of onshore in 
accordance with any applicable solid waste and hazardous substance 
management and disposal requirements.

[85 FR 43477, July 17, 2020]



Sec.  1700.38  Welldeck discharges.

    (a) Welldeck discharges that contain graywater from smaller vessels 
are prohibited.
    (b) Welldeck discharges containing washdown from gas turbine engines 
are prohibited within three miles of the United States and to the 
greatest extent practicable must be discharged seaward of waters subject 
to UNDS.
    (c) Welldeck discharges from equipment and vehicle washdowns must 
not contain garbage and must not contain oil in quantities that:
    (1) Cause a film or sheen upon or discoloration of the surface of 
the water or adjoining shorelines; or
    (2) Cause a sludge or emulsion to be deposited beneath the surface 
of the water or upon adjoining shorelines; or
    (3) Contain an oil content above 15 ppm as measured by EPA Method 
1664a or other appropriate method for determination of oil content as 
accepted by the International Maritime Organization (IMO) (e.g., ISO 
Method 9377) or U.S. Coast Guard; or
    (4) Otherwise are harmful to the public health or welfare of the 
United States.



Sec.  1700.39  Exceptions.

    (a) Notwithstanding each of the MPCD performance standards 
established in this Part, a vessel of the Armed Forces is authorized to 
discharge, into waters subject to UNDS, when the PIC or their designated 
representative determines that such discharge is necessary to prevent 
loss of life, personal injury, vessel endangerment, or severe damage to 
the vessel.

[[Page 756]]

    (b) A vessel of the Armed Forces must maintain the following records 
for all discharges under paragraph (a) of this section:
    (1) Name and title of the PIC who determined the necessity of the 
discharge;
    (2) Date, location, and estimated volume of the discharge;
    (3) Explanation of the reason the discharge occurred; and
    (4) Actions taken to avoid, minimize, or otherwise mitigate the 
discharge.
    (c) All records prepared under paragraph (b) of this section must be 
maintained in accordance with Sec.  1700.41.



Sec.  1700.40  Commingling of discharges.

    If two or more regulated discharge streams are combined into one, 
the resulting discharge stream must meet the requirements applicable to 
all discharge streams that are combined prior to discharge.



Sec.  1700.41  Records.

    (a) All records must be generated and maintained in the ship's logs 
(main, engineering, and/or damage control) or an UNDS Record Book and 
must include the following information:
    (1) Vessel owner information (e.g., U.S. Navy, U.S. Coast Guard);
    (2) Vessel name and class; and
    (3) Name of the PIC.
    (b) The PIC must maintain complete records of the following 
information:
    (1) Any inspection or recordkeeping requirement as specified in 
Sec. Sec.  1700.14 through 1700.38;
    (2) Any instance of an exception and the associated recordkeeping 
requirements as specified in Sec.  1700.39; and
    (3) Any instance of non-compliance with any of the performance 
standards as specified in Sec. Sec.  1700.14 through 1700.38. The 
information recorded must include the following:
    (i) Description of any non-compliance and its cause;
    (ii) Date of non-compliance;
    (iii) Period of non-compliance (time and duration);
    (iv) Location of the vessel during non-compliance;
    (v) Corrective action taken;
    (vi) Steps taken or planned to reduce, eliminate, and prevent non-
compliance in the future; and
    (vii) If the non-compliance has not been corrected, an estimate of 
the time the non-compliance is expected to continue.
    (c) All records prepared under this section must be maintained for a 
period of five years from the date they are created. The information in 
this paragraph will be available to the EPA, states, or the U.S. Coast 
Guard upon request. Any information made available upon request must be 
appropriately classified, as applicable, and handled in accordance with 
applicable legal requirements regarding national security.



Sec.  1700.42  Non-compliance reports.

    The PIC must report any non-compliance, including the information as 
required under Sec.  1700.41, to the Armed Service's designated office 
in writing and/or electronically within five days of the time the PIC 
becomes aware of the circumstances.

                       PARTS 1701	1799 [RESERVED]

[[Page 757]]



         CHAPTER VIII--GULF COAST ECOSYSTEM RESTORATION COUNCIL




  --------------------------------------------------------------------
Part                                                                Page
1800            Spill Impact Component......................         759
1801-1849

 [Reserved]

1850            Availability of records.....................         762
1851-1899

 [Reserved]

[[Page 759]]



PART 1800_SPILL IMPACT COMPONENT--Table of Contents



                          Subpart A_Definitions

Sec.
1800.1 Definitions.

      Subpart B_Minimum Allocation Available for Planning Purposes

1800.10 Purpose.
1800.20 Minimum allocation available for planning purposes.

                     Subpart C_Spill Impact Formula

1800.100 Purpose.
1800.101 General formula.
1800.200 Oiled shoreline.
1800.201 Miles of shoreline that experienced oiling as a result of the 
          Deepwater Horizon oil spill.
1800.202 Proportionate number of miles of shoreline that experienced 
          oiling as a result of the Deepwater Horizon oil spill.
1800.300 Inverse proportion of the average distance from Deepwater 
          Horizon at the time of the explosion.
1800.301 Distances from the Deepwater Horizon at the time of the 
          explosion.
1800.302 Inverse proportions.
1800.400 Coastal county populations.
1800.401 Decennial census data.
1800.402 Distribution based on average population.
1800.500 Allocation.

    Authority: 33 U.S.C. 1321(t).

    Source: 80 FR 1586, Jan. 13, 2015, unless otherwise noted.



                          Subpart A_Definitions



Sec.  1800.1  Definitions.

    As used in this part:
    Deepwater Horizon oil spill means the blowout and explosion of the 
mobile offshore drilling unit Deepwater Horizon that occurred on April 
20, 2010, and resulting hydrocarbon releases into the environment.
    Gulf Coast State means any of the States of Alabama, Florida, 
Louisiana, Mississippi, and Texas.
    Gulf Consortium means the consortium of Florida counties formed to 
develop the Florida State Expenditure Plan pursuant to 33 U.S.C. 
1321(t)(3)(B)(iii)(II).
    Inverse proportion means a mathematical relation between two 
quantities such that one proportionally increases as the other 
decreases.
    Minimum allocation means the amount made available to each Gulf 
Coast State which totals at least five percent of the total allocation 
made available under the Spill Impact Component.
    RESTORE Act means the Resources and Ecosystems Sustainability, 
Tourist Opportunities, and Revived Economies of the Gulf Coast States 
Act of 2012.
    Spill Impact Component means the component of the Gulf RESTORE 
program authorized by section 311(t)(3) of the Federal Water Pollution 
Control Act (33 U.S.C. 1321(t)(3)), as added by section 1603 of the Act, 
in which Gulf Coast States are provided funds by the Council according 
to a formula that the Council establishes by regulation, using criteria 
listed in the Act.
    Spill Impact Formula means the formula established by the Council in 
accordance with section 311(t)(3)(A)(ii) of the Federal Water Pollution 
Control Act, as added by section 1603 thereof.
    State Expenditure Plan means the plan for expenditure of amounts 
disbursed under the Spill Impact Component that each Gulf Coast State 
must submit to the Council for approval.
    Treasury means the U.S. Department of the Treasury, the Secretary of 
the Treasury, or his/her designee.
    Trust Fund means the Gulf Coast Restoration Trust Fund.

[80 FR 1586, Jan. 13, 2015, as amended at 80 FR 77584, Dec. 15, 2015]



      Subpart B_Minimum Allocation Available for Planning Purposes



Sec.  1800.10  Purpose.

    This subpart establishes that up to the statutory minimum allocation 
(five percent) is available under the Spill Impact Component of the 
Resources and Ecosystems Sustainability, Tourist Opportunities, and 
Revived Economies of the Gulf Coast States Act of 2012 (RESTORE Act) 
(Pub. L. 112-141, 126 Stat. 405, 588-607) for planning purposes 
associated with development of a State Expenditure Plan.

[[Page 760]]



Sec.  1800.20  Minimum allocation available for planning purposes.

    A Gulf Coast State or its administrative agent, or the Gulf 
Consortium, may apply to the Council for a grant to use the minimum 
allocation available under the Spill Impact Component of the RESTORE Act 
for planning purposes. These planning purposes are limited to 
development of a State Expenditure Plan, and includes conceptual design 
and feasibility studies related to specific projects. It does not 
include engineering and environmental studies related to specific 
projects. It also does not include any pre-award costs incurred prior to 
August 22, 2014.



                     Subpart C_Spill Impact Formula

    Source: 80 FR 77584, Dec. 15, 2015, unless otherwise noted.



Sec.  1800.100  Purpose.

    This subpart establishes the formula applicable to the Spill Impact 
Component authorized under the RESTORE Act (Pub. L. 112-141, 126 Stat. 
405, 588-607).



Sec.  1800.101  General formula.

    The RESTORE Act provides that thirty percent (30%) of the funds made 
available from the Trust Fund for the Oil Spill Impact Component be 
disbursed to each of the Gulf Coast States of Alabama, Florida, 
Louisiana, Mississippi and Texas based on a formula established by the 
Council (Spill Impact Formula), through a regulation, that is based on a 
weighted average of the following criteria:
    (a) Forty percent (40%) based on the proportionate number of miles 
of shoreline in each Gulf Coast State that experienced oiling on or 
before April 10, 2011, compared to the total number of miles of 
shoreline that experienced oiling as a result of the Deepwater Horizon 
oil spill;
    (b) Forty percent (40%) based on the inverse proportion of the 
average distance from the mobile offshore drilling unit Deepwater 
Horizon at the time of the explosion to the nearest and farthest point 
of the shoreline that experienced oiling of each Gulf Coast State; and
    (c) Twenty percent (20%) based on the average population in the 2010 
Decennial Census of coastal counties bordering the Gulf of Mexico within 
each Gulf Coast State.



Sec.  1800.200  Oiled shoreline.

    Solely for the purpose of calculating the Spill Impact Formula, the 
following shall apply, rounded to one decimal place with respect to 
miles of shoreline:



Sec.  1800.201  Miles of shoreline that experienced oiling as
a result of the Deepwater Horizon oil spill.

    According to Shoreline Cleanup and Assessment Technique and Rapid 
Assessment Technique data provided by the United States Coast Guard, the 
miles of shoreline that experienced oiling on or before April 10, 2011 
for each Gulf Coast State are:
    (a) Alabama--89.8 miles.
    (b) Florida--174.6 miles.
    (c) Louisiana--658.3 miles.
    (d) Mississippi--158.6 miles.
    (e) Texas--36.0 miles.



Sec.  1800.202  Proportionate number of miles of shoreline that
experienced oiling as a result of the Deepwater Horizon oil spill.

    The proportionate number of miles for each Gulf Coast State is 
determined by dividing each Gulf Coast State's number of miles of oiled 
shoreline determined in Sec.  1800.201 by the total number of affected 
miles. This calculation yields the following:
    (a) Alabama--8.04%.
    (b) Florida--15.63%.
    (c) Louisiana--58.92%.
    (d) Mississippi--14.19%.
    (e) Texas--3.22%.



Sec.  1800.300  Inverse proportion of the average distance from
Deepwater Horizon at the time of the explosion.

    Solely for the purpose of calculating the Spill Impact Formula, the 
following shall apply, rounded to one decimal place with respect to 
distance:



Sec.  1800.301  Distances from the Deepwater Horizon at the time of the explosion.

    (a) Alabama--The distance from the nearest point of the Alabama 
shoreline

[[Page 761]]

that experienced oiling from the Deepwater Horizon oil spill was 89.2 
miles. The distance from the farthest point of the Alabama shoreline 
that experienced oiling from the Deepwater Horizon oil spill was 103.7 
miles. The average of these two distances is 96.5 miles.
    (b) Florida--The distance from the nearest point of the Florida 
shoreline that experienced oiling from the Deepwater Horizon oil spill 
was 102.3 miles. The distance from the farthest point of the Florida 
shoreline that experienced oiling from the Deepwater Horizon oil spill 
was 207.6 miles. The average of these two distances is 154.9 miles.
    (c) Louisiana--The distance from the nearest point of the Louisiana 
shoreline that experienced oiling from the Deepwater Horizon oil spill 
was 43.5 miles. The distance from the farthest point of the Louisiana 
shoreline that experienced oiling from the Deepwater Horizon oil spill 
was 213.7 miles. The average of these two distances is 128.6 miles.
    (d) Mississippi--The distance from the nearest point of the 
Mississippi shoreline that experienced oiling from the Deepwater Horizon 
oil spill was 87.7 miles. The distance from the farthest point of the 
Mississippi shoreline that experienced oiling from the Deepwater Horizon 
oil spill was 107.9 miles. The average of these two distances is 97.8 
miles.
    (e) Texas--The distance from the nearest point of the Texas 
shoreline that experienced oiling from the Deepwater Horizon oil spill 
was 306.2 miles. The distance from the farthest point of the Texas 
shoreline that experienced oiling from the Deepwater Horizon oil spill 
was 356.5 miles. The average of these two distances is 331.3 miles.



Sec.  1800.302  Inverse proportions.

    The inverse proportion for each Gulf Coast State is determined by 
summing the proportional average distances determined in Sec.  1800.301 
and taking the inverse. This calculation yields the following:
    (a) Alabama--27.39%.
    (b) Florida--17.06%.
    (c) Louisiana--20.55%.
    (d) Mississippi--27.02%.
    (e) Texas--7.98%.



Sec.  1800.400  Coastal county populations.

    Solely for the purpose of calculating the Spill Impact Formula, the 
coastal counties bordering the Gulf of Mexico within each Gulf Coast 
State are:
    (a) The Alabama Coastal Counties, consisting of Baldwin and Mobile 
counties;
    (b) The Florida Coastal Counties, consisting of Bay, Charlotte, 
Citrus, Collier, Dixie, Escambia, Franklin, Gulf, Hernando, 
Hillsborough, Jefferson, Lee, Levy, Manatee, Monroe, Okaloosa, Pasco, 
Pinellas, Santa Rosa, Sarasota, Taylor, Wakulla, and Walton counties;
    (c) The Louisiana Coastal Parishes, consisting of Cameron, Iberia, 
Jefferson, Lafourche, Orleans, Plaquemines, St. Bernard, St. Mary, St. 
Tammany, Terrebonne, and Vermilion parishes;
    (d) The Mississippi Coastal Counties, consisting of Hancock, 
Harrison, and Jackson counties; and
    (e) The Texas Coastal Counties, consisting of Aransas, Brazoria, 
Calhoun, Cameron, Chambers, Galveston, Jefferson, Kennedy, Kleberg, 
Matagorda, Nueces, and Willacy counties.



Sec.  1800.401  Decennial census data.

    The average populations in the 2010 decennial census for each Gulf 
Coast State, rounded to the nearest whole number, are:
    (a) For the Alabama Coastal Counties, 297,629 persons;
    (b) For the Florida Coastal Counties, 252,459 persons;
    (c) For the Louisiana Coastal Parishes, 133,633 persons;
    (d) For the Mississippi Coastal Counties,123,567 persons; and
    (e) For the Texas Coastal Counties, 147,845 persons.



Sec.  1800.402  Distribution based on average population.

    The distribution of funds based on average populations for each Gulf 
Coast State is determined by dividing the average population determined 
in Sec.  1800.401 by the sum of those average populations. This 
calculation yields the following results:
    (a) Alabama--31.16%.
    (b) Florida--26.43%.
    (c) Louisiana--13.99%.
    (d) Mississippi--12.94%.

[[Page 762]]

    (e) Texas--15.48%.



Sec.  1800.500  Allocation.

    Using the data from Sec. Sec.  1800.200 through 1800.402 of this 
subpart in the formula provided in Sec.  1800.101 of this subpart yields 
the following allocation for each Gulf Coast State:
    (a) Alabama--20.40%.
    (b) Florida--18.36%.
    (c) Louisiana--34.59%.
    (d) Mississippi--19.07%.
    (e) Texas--7.58%.

                       PARTS 1801	1849 [RESERVED]



PART 1850_AVAILABILITY OF RECORDS--Table of Contents



 Subpart A_Production or Disclosure Under the Freedom of Information Act

Sec.
1850.1 Purpose and scope.
1850.2 Definitions.
1850.3 General provisions.
1850.4 Public reading room.
1850.5 Requirements for making requests.
1850.6 Responding to requests.
1850.7 Appeals.
1850.8 Authority to determine.
1850.9 Maintenance of files.
1850.10 Fees.
1850.11 Requests for confidential treatment of business information.
1850.12 Requests for access to confidential commercial or financial 
          information.
1850.13 Classified information.

        Subpart B_Production or Disclosure Under the Privacy Act

1850.31 Purpose and scope.
1850.32 Definitions.
1850.33 Procedures for requests pertaining to individual records in a 
          record system.
1850.34 Times, places, and requirements for identification of 
          individuals making requests.
1850.35 Disclosure of requested information to individuals.
1850.36 Special procedures: Medical records.
1850.37 Request for correction or amendment to record.
1850.38 Council review of request for correction or amendment to record.
1850.39 Appeal of initial adverse agency determination on correction or 
          amendment.
1850.40 Disclosure of record to person other than the individual to whom 
          it pertains.
1850.41 Fees.
1850.42 Penalties.

    Authority: 33 U.S.C. 1321(t); 5 U.S.C. 552; 5 U.S.C. 552a.

    Source: 80 FR 29451, May 22, 2015, unless otherwise noted.



 Subpart A_Production or Disclosure Under the Freedom of Information Act



Sec.  1850.1  Purpose and scope.

    This subpart contains the regulations of the Gulf Coast Ecosystem 
Restoration Council (Council) implementing the Freedom of Information 
Act (FOIA) (5 U.S.C. 552), as amended. These regulations supplement the 
FOIA, which provides more detail regarding requesters' rights and the 
records the Council may release.
    The regulations of this subpart provide information concerning the 
procedures by which records may be obtained from the Council. Official 
records of the Council made available pursuant to the requirements of 
the FOIA shall be furnished to members of the public only as prescribed 
by this subpart. Information routinely provided to the public as part of 
a regular Council activity (for example, press releases) may be provided 
to the public without following this subpart.
    The FOIA applies to third-party requests for documents concerning 
the general activities of the Government, and of the Council in 
particular. When a U.S. citizen or an individual lawfully admitted for 
permanent residence requests access to his or her own records, he/she is 
making a first-person Privacy Act request, not a FOIA request, subject 
to subpart B of these rules. The Council maintains records about 
individuals under the individual's name or personal identifier. Although 
the Council determines whether a request is a FOIA request or a Privacy 
Act request, the Council processes requests in accordance with both 
laws. This provides the greatest degree of lawful access to requesters 
while safeguarding individuals' personal privacy.



Sec.  1850.2  Definitions.

    (a) Commercial Use Request means a request from or on behalf of one 
who seeks information for a use or purpose that furthers the commercial, 
trade, or profit interests of the requester or the

[[Page 763]]

person on whose behalf the request is made.
    (b) Confidential Commercial Information means commercial or 
financial information, obtained by the Council from a submitter, that 
may contain information exempt from release under Exemption 4 of FOIA, 5 
U.S.C. 552(b)(4).
    (c) Council means to the Gulf Coast Ecosystem Restoration Council.
    (d) Days, unless stated as ``calendar days,'' are business days and 
do not include Saturday, Sunday, or federal holidays.
    (e) Direct costs means those expenses the Council actually incurs in 
searching for and duplicating (and, in the case of commercial 
requesters, reviewing) documents in response to a request made under 
Sec.  1850.5. Direct costs include, for example, the labor costs of the 
employee performing the work (the basic rate of pay for the employee, 
plus 16 percent of that rate to cover benefits) and the cost of 
operating duplicating machinery. Not included in direct costs are 
overhead expenses such as costs of space and heating or lighting of the 
facility in which the documents are stored.
    (f) Duplication means the making a copy of a document, or other 
information contained in it, necessary to respond to a FOIA request. 
Copies may take the form of paper, microfilm, audio-visual materials, or 
electronic records, among others. The Council shall honor a requester's 
specified preference of form or format of disclosure if the record is 
readily reproducible with reasonable efforts in the requested form or 
format.
    (g) Educational institution means a preschool, a public or private 
elementary or secondary school, or an institution of undergraduate 
higher education, graduate higher education, professional education, or 
an institution of vocational education that operates a program of 
scholarly research.
    (h) Fee category means one of the three categories that agencies 
place requesters in for the purpose of determining whether a requester 
will be charged fees for search, review and duplication. The three fee 
categories are:
    (1) Commercial requesters;
    (2) Non-commercial scientific or educational institutions or news 
media requesters; and
    (3) All other requesters.
    (i) Fee waiver means the waiver or reduction of processing fees if a 
requester can demonstrate that certain statutory standards are 
satisfied, including that the information is in the public interest and 
is not requested for a commercial interest.
    (j) FOIA Public Liaison means an agency official who is responsible 
for assisting in reducing delays, increasing transparency and 
understanding of the status of requests, and assisting in the resolution 
of disputes.
    (k) News means information about current events or that would be of 
current interest to the public.
    (l) Noncommercial scientific institution means an institution that 
is not operated on a ``commercial'' basis (as that term is used in this 
section) and which is operated solely for the purpose of conducting 
scientific research, the results of which are not intended to promote 
any particular product or industry.
    (m) Perfected request means a written FOIA request that meets all of 
the criteria set forth in Sec.  1850.5.
    (n) Reading room means a location where records are available for 
review pursuant to 5 U.S.C. 552(a)(2).
    (o) Records under the FOIA include all Government records, 
regardless of format, medium or physical characteristics, and electronic 
records and information, audiotapes, videotapes, Compact Disks, DVDs, 
and photographs.
    (p) Records Management Officer means the person designated by the 
Executive Director of the Council to oversee all aspects of the 
Council's records management program, including FOIA.
    (q) Representative of the news media, or news media requester, means 
any person or entity organized and operated to publish or broadcast news 
to the public that actively gathers information of potential interest to 
a segment of the public, uses its editorial skills to turn the raw 
materials into a distinct work, and distributes the work to an audience. 
Examples of news-media entities are television or radio stations 
broadcasting to the public at large, and publishers of periodicals that 
disseminate

[[Page 764]]

``news'' and make their products available through a variety of means to 
the general public including news organizations that disseminate solely 
on the Internet. To be in this category, a requester must not be seeking 
the requested records for a commercial use. A request for records that 
supports the news-dissemination function of the requester shall not be 
considered to be for a commercial use. A ``freelance journalist'' shall 
be regarded as working for a news-media entity if the journalist can 
demonstrate a solid basis for expecting publication through that entity, 
whether or not the journalist is actually employed by the entity. A 
publication contract would be the clearest proof, but the Council shall 
also look to the past publication record of a requester in making this 
determination. The Council's decision to grant a requester media status 
will be made on a case-by-case basis based upon the requester's intended 
use of the material.
    (r) Requester means any person, partnership, corporation, 
association, or foreign or State or local government, which has made a 
request to access a Council record under FOIA.
    (s) Requester category means one of the three categories in which 
agencies place requesters to determine whether the agency will charge a 
requester fees for search, review, and duplication. The categories 
include commercial requesters, non-commercial scientific or educational 
institutions or news media requesters, and all other requesters.
    (t) Review means the examination of a record located in response to 
a request in order to determine whether any portion of it is exempt from 
disclosure. Review time includes processing any record for disclosure, 
such as doing all that is necessary to prepare the record for 
disclosure, including the process of redacting it and marking any 
applicable exemptions. Review costs are recoverable even if a record 
ultimately is not disclosed. Review time includes time spent obtaining 
and considering any formal objection to disclosure made by a business 
submitter under Sec.  1850.12 but does not include time spent resolving 
general legal or policy issues regarding the application of exemptions.
    (u) Search means the process of looking for and retrieving documents 
or information that is responsive to a request. Search time includes 
page-by-page or line-by-line identification of information within 
documents and also includes reasonable efforts to locate and retrieve 
information from records maintained in electronic form or format.
    (v) Submitter means any person or entity from whom the Council 
obtains confidential commercial information, directly or indirectly.
    (w) Unusual circumstances include situations in which the Council 
must:
    (1) Search for and collect the requested agency records from field 
facilities or other establishments that are separate from the office 
processing the request;
    (2) Search for, collect, and appropriately examine a voluminous 
amount of separate and distinct records that are the subject of a single 
request; or
    (3) Consult with another Federal agency having a substantial 
interest in the determination of the FOIA request.



Sec.  1850.3  General provisions.

    The Council shall prepare an annual report to the Attorney General 
of the United States regarding its FOIA activities in accordance with 5 
U.S.C. 552(e).



Sec.  1850.4  Public reading room.

    The Council maintains an electronic public reading room on its Web 
site, http://www.restorethegulf.gov, which contains the records FOIA 
requires the Council to make available for public inspection and 
copying, as well as additional records of interest to the public.



Sec.  1850.5  Requirements for making requests.

    (a) Type of records made available. The Council shall make available 
upon request, pursuant to the procedures in this section and subject to 
the exceptions set forth in FOIA, all records of the Council that are 
not available under Sec.  1850.4. The Council's policy is to make 
discretionary disclosures of records or information otherwise exempt 
from disclosure under FOIA unless the Council reasonably foresees

[[Page 765]]

that such disclosure would harm an interest protected by one or more 
FOIA exemptions, or otherwise prohibited by law. This policy does not 
create any enforceable right in court.
    (b) Procedures for requesting records. A request for records shall 
reasonably describe the records in a way that enables Council staff to 
identify and produce the records with reasonable effort. The requester 
should include as much specific information as possible regarding dates, 
titles, and names of individuals. In cases where the request requires 
production of voluminous records, or is not reasonably described, a 
Council representative may suggest the requester, or the individual 
acting on the requester's behalf, to verify the scope of the request 
and, if possible, narrow the request. Once narrowed, the Council will 
process the request. All requests must be submitted in writing 
(including by email, fax or mail) to the Council's Records Management 
Officer. Requesters shall clearly mark a request as a ``Freedom of 
Information Act Request'' or ``FOIA Request'' on the front of the 
envelope or in the subject line of the email.
    (c) Contents of request. The request, at minimum, shall contain the 
following information:
    (1) The name, telephone number, and non-electronic address of the 
requester;
    (2) Whether the requested information is intended for commercial 
use, or whether the requester represents an education or noncommercial 
scientific institution, or news media; and
    (3) A statement agreeing to pay the applicable fees, identifying any 
fee limitation desired, or requesting a waiver or reduction of fees that 
satisfies Sec.  1850.10(j)(1) to (3).
    (d) Perfected requests. The requester must meet all the requirements 
in this section to perfect a request. The Council will only process 
perfected requests.
    (e) Requests by an individual for Council records pertaining to that 
individual. An individual who wishes to inspect or obtain copies of 
Council records that pertain to that individual must file a request in 
accordance with subpart B of this part.
    (f) Requests for Council records pertaining to another individual. 
Where a request for records pertains to a third party, a requester may 
receive greater access by submitting a notarized authorization signed by 
that individual or a declaration by that individual made in compliance 
with the requirements set forth in 28 U.S.C. 1746, authorizing 
disclosure of the records to the requester, or by submitting proof the 
individual is deceased (e.g. a copy of the death certificate or an 
obituary). The Council may require a requester to supply additional 
information if necessary to verify that a particular individual has 
consented to disclosure.
    (g) Requesters may submit a request for records, expedited 
processing or waiver of fees by writing directly to the Records 
Management Officer via email at [email protected], or first 
class United States mail at 500 Poydras Street, Suite 1117, New Orleans, 
LA 70130.
    (h) Any Council officer or employee who receives a written Freedom 
of Information Act request shall promptly forward it to the Records 
Management Officer. Any Council officer or employee who receives an oral 
request under the Freedom of Information Act shall inform the person 
making the request that it must be in writing and also inform such 
person of the provisions of this subpart.



Sec.  1850.6  Responding to requests.

    (a) Receipt and processing. The date of receipt for any request, 
including one that is addressed incorrectly or that is referred to the 
Council by another agency, is the date the Council actually receives the 
request. The Council normally will process requests in the order they 
are received. However, in the Records Management Officer's discretion, 
the Council may use two or more processing tracks by distinguishing 
between simple and more complex requests based on the number of pages 
involved, or some other measure of the amount of work and/or time needed 
to process the request, and whether the request qualifies for expedited 
processing as defined by paragraph (d) of this section. When using 
multi-track processing, the Records Management Officer may provide 
requesters in the complex track(s) with an opportunity to limit the 
scope of

[[Page 766]]

their requests to qualify for the simple track and faster processing.
    (b) Authorization. The Records Management Officer and other persons 
designated by the Council's Executive Director are solely authorized to 
grant or deny any request for Council records.
    (c) Timing. (1) When a requester submits a request in accordance 
with Sec.  1850.5, the Records Management Officer shall inform the 
requester of the determination concerning that request within 20 days 
from receipt of the request, unless ``unusual circumstances'' exist, as 
defined in Sec.  1850.2(w). The Records Management Officer also shall 
provide requesters with a unique tracking number, an estimated date of 
completion (once the request is perfected), and a fee estimate (when 
applicable). The Records Management Officer shall also include in the 
Council's acknowledgment letter a brief description of the subject of 
the request.
    (2) When additional time is required as a result of ``unusual 
circumstances,'' as defined in Sec.  1850.2(w), the Records Management 
Officer shall, within the statutory 20 day period, issue to the 
requester a brief written statement of the reason for the delay and an 
indication of the date on which it is expected that a determination as 
to disclosure will be forthcoming. If more than 10 additional days are 
needed, the requester shall be notified and provided an opportunity to 
limit the scope of the request or to arrange for an alternate time frame 
for processing the request.
    (3) The Council may toll the statutory time period to issue its 
determination on a FOIA request one time during the processing of the 
request to obtain clarification from the requester. The statutory time 
period to issue the determination on disclosure is tolled until the 
Council receives the information reasonably requested from the 
requester. The Council may also toll the statutory time period to issue 
the determination to clarify with the requester issues regarding fees. 
There is no limit on the number of times the agency may request 
clarifying fee information from the requester.
    (d) Expedited processing. (1) A requester may request expedited 
processing by submitting a statement, certified to be true and correct 
to the best of that person's knowledge and belief, that demonstrates a 
compelling need for records, as defined in 5 U.S.C. 552(a)(6)(E)(v).
    (2) The Records Management Officer will notify a requester of the 
determination to grant or deny a request for expedited processing within 
ten days of receipt of the request. If the Records Management Officer 
grants the request for expedited processing, the Council staff shall 
process the request as soon as practicable subject to Sec.  1850.10(d) 
and (e). If the Records Management Officer denies the request for 
expedited processing, the requester may file an appeal in accordance 
with the process described in Sec.  1850.7.
    (3) The Council staff will give expedited treatment to a request 
when the Records Management Officer determines the requester has 
established one of the following:
    (i) Circumstances in which the lack of expedited treatment 
reasonably could be expected to pose an imminent threat to the life or 
physical safety of an individual;
    (ii) An urgency to inform the public about an actual or alleged 
Federal Government activity, if made by an individual primarily engaged 
in disseminating information;
    (iii) The loss of substantial due process rights;
    (iv) A matter of widespread and exceptional media interest raising 
possible questions about the Federal government's integrity which 
affects public confidence; or
    (4) These procedures for expedited processing also apply to requests 
for expedited processing of administrative appeals.
    (e) Denials. If the Records Management Officer denies the request in 
whole or part, the Records Management Officer will inform the requester 
in writing and include the following:
    (1) A brief statement of the reason(s) for the denial, including 
applicable FOIA exemption(s) and a description of those exemptions;
    (2) An estimate of the volume of records or information withheld;
    (3) If technically feasible, the precise amount of information 
deleted at the place in the record where the deletion was made, and the 
exemption under

[[Page 767]]

which a deletion is made on the released portion of the record, unless 
including that information would harm an interest protected by the 
exemption;
    (4) The name and title or position of the person responsible for the 
denial of the request;
    (5) The requester's right to appeal any such denial and the title 
and address of the official to whom such appeal is to be addressed; and
    (6) The requirement that the appeal be received within 45 days of 
the date of the denial.
    (f) Referrals to another agency. (1) When the Council receives a 
request for a record (or a portion thereof) in its possession that 
originated with another Federal agency subject to the FOIA, the Council 
shall, except as provided in paragraph (f)(4) of this section, refer the 
record to that agency for direct response to the requester. However, if 
the Council and the originating agency jointly agree that the Council is 
in the best position to respond regarding the record, then the record 
may be handled as a consultation.
    (2) Whenever the Council refers any part of the responsibility for 
responding to a request to another agency, it shall document the 
referral, maintain a copy of the record that it refers, and notify the 
requester of the referral and inform the requester of the name of the 
agency to which the record was referred, including that agency's FOIA 
contact information.
    (3) The Council's response to an appeal will advise the requester 
that the 2007 FOIA amendments created the Office of Government 
Information Services (OGIS) to offer mediation services to resolve 
disputes between FOIA requesters and Federal agencies as a non-exclusive 
alternative to litigation. A requester may contact OGIS in any of the 
following ways: Office of Government Information Services, National 
Archives and Records Administration, 8601 Adelphi Road--OGIS, College 
Park, MD 20740, ogis.archives.gov, Email: [email protected], Telephone: 202-
741-5770, Facsimile: 202-741-5769, Toll-free: 1-877-684-6448.
    (4) The referral procedure is not appropriate where disclosure of 
the identity of the agency, typically a law enforcement agency or 
Intelligence Community agency, to which the referral would be made could 
harm an interest protected by an applicable exemption, such as the 
exemptions that protect personal privacy and national security 
interests. In such instances, in order to avoid harm to an interest 
protected by an applicable exemption, the Council shall coordinate with 
the originating agency to seek its views on the disclosability of the 
record. The release determination for the record that is the subject of 
the coordination shall then be conveyed to the requester by the Council.
    (g) Consulting with another agency. In instances where a record is 
requested that originated with the Council and another agency has a 
significant interest in the record (or a portion thereof), the Council 
shall consult with that agency before responding to a requester. When 
the Council receives a request for a record (or a portion thereof) in 
its possession that originated with another agency that is not subject 
to the FOIA, the Council shall consult with that agency before 
responding to the requester.
    (h) Providing responsive records. (1) Council staff shall send a 
copy of records or portions of records responsive to the request to the 
requester by regular United States mail to the address indicated in the 
request or by email to the email address provided by the requester, 
unless the requester makes other acceptable arrangements or the Council 
deems it appropriate to send the records by other means. The Council 
shall provide a copy of the record in any form or format requested if 
the record is readily reproducible in that form or format. The Council 
need not provide more than one copy of any record to a requester.
    (2) The Records Management Officer shall provide any reasonably 
segregable portion of a record that is responsive to the request after 
redacting those portions that are exempt under FOIA or this section.
    (3) The Council is not required to create, compile, prepare or 
obtain from outside the Council a record to satisfy a request. 
Retrieving data from a Council database or running a report from a 
database is permissible.

[[Page 768]]

    (i) Prohibition against disclosure. Except as provided in this 
subpart, no member or employee of the Council shall disclose or permit 
the disclosure of any non-public information of the Council to any 
person (other than Council members, employees, or agents properly 
entitled to such information for the performance of their official 
duties), unless required by law to do so.



Sec.  1850.7  Appeals.

    (a) Requesters may administratively appeal an adverse determination 
regarding a request by writing directly to the General Counsel via email 
at [email protected] or first class United States mail 
at 500 Poydras Street, Suite 1117, New Orleans, LA 70130. Administrative 
appeals sent to other individuals or addresses are not considered 
perfected. An adverse determination is a denial of a request and 
includes decisions that: The requested record is exempt, in whole or in 
part; the information requested is not a record subject to the FOIA; the 
requested record does not exist, cannot be located, or has previously 
been destroyed; or the requested record is not readily reproducible in 
the form or format sought by the requester. Adverse determinations also 
include denials involving fees or fee waiver matters or denials of 
requests for expedited processing.
    (b) FOIA administrative appeals must be in writing and should 
contain the phrase ``FOIA Appeal'' on the front of the envelope or in 
the subject line of the electronic mail.
    (c) Appellants are encouraged to include a copy of the original 
request and the initial denial (if any) in the appeal. The appeal letter 
may include as much or as little related information as the appellant 
wishes, as long as it clearly identifies the component determination 
(including the assigned request number, if known) that is being 
appealed.
    (d) Requesters submitting an administrative appeal of an adverse 
determination must ensure that the Council receives the appeal within 45 
days of the date of the denial letter.
    (e) Upon receipt of an administrative appeal, Council staff shall 
inform the requester within 20 days of the determination on that appeal.
    (f) The determination on an appeal shall be in writing and, when it 
denies the appeal, in whole or in part, the letter to the requester 
shall include:
    (1) A brief explanation of the basis for the denial, including a 
list of the applicable FOIA exemptions and a description of how they 
apply;
    (2) A statement that the decision is final for the Council;
    (3) Notification that judicial review of the denial is available in 
the district court of the United States in the district in which the 
requester resides, or has his or her principal place of business, or in 
which the agency records are located, or in the District of Columbia; 
and
    (4) The name and title or position of the official responsible for 
denying the appeal.



Sec.  1850.8  Authority to determine.

    The Records Management Officer or Council Executive Director, when 
receiving a request pursuant to these regulations, shall grant or deny 
such request. That decision shall be final, subject only to 
administrative appeal as provided in Sec.  1850.7. The Council General 
Counsel shall deny or grant an administrative appeal requested under 
Sec.  1850.7.



Sec.  1850.9  Maintenance of files.

    The Records Management Officer shall maintain files containing all 
material required to be retained by or furnished to them under this 
subpart. The Council shall preserve all correspondence pertaining to the 
FOIA requests that it receives, as well as copies of all requested 
records, until a General Records Schedule (GRS) published by the 
National Archives and Records Administration (NARA) or another NARA-
approved records schedule authorizes the office to dispose of or destroy 
the records. All materials identified as responsive to a FOIA request 
will be retained while the request or a related appeal or lawsuit is 
pending even otherwise authorized for disposal or destruction under a 
GRS or other NARA-approved records schedule. The material shall be filed 
by a unique tracking number.

[[Page 769]]



Sec.  1850.10  Fees.

    (a) Generally. Except as provided elsewhere in this section, the 
Records Management Officer shall assess fees where applicable in 
accordance with this section for search, review, and duplication of 
records requested. The Records Management Officer shall also have 
authority to furnish documents without any charge or at a reduced charge 
if disclosure of the information is in the public interest because it is 
likely to contribute significantly to public understanding of the 
operations or activities of the government and is not primarily in the 
commercial interest of the requester.
    (b)(1) Fee schedule; waiver of fees. The fees applicable to a 
request for Council records pursuant to Sec.  1850.5 are set forth in 
the following uniform fee schedule:

------------------------------------------------------------------------
                Service                                Rate
------------------------------------------------------------------------
(i) Manual search......................  Actual salary rate of employee
                                          involved, plus 16 percent of
                                          salary rate to cover benefits.
(ii) Computerized search...............  Actual direct cost, including
                                          operator time.
(iii) Duplication of records:
    (A) Paper copy reproduction........  $0.05 per page.
    (B) Other reproduction (e.g.,        Actual direct cost, including
     computer disk or printout,           operator time.
     microfilm, microfiche, or
     microform).
(iv) Review of records (including        Actual salary rate of employee
 redaction).                              involved, plus 16 percent of
                                          salary rate to cover benefits.
------------------------------------------------------------------------

    (2) Search. (i) The Council shall charge search fees for all 
requests, subject to the limitations of paragraph (b)(5) of this 
section. The Records Management Officer shall charge for time spent 
searching for responsive records, even if no responsive record is 
located or if the Records Management Officer withholds records located 
as entirely exempt from disclosure. Search fees shall equal the direct 
costs of conducting the search by the Council employee involved, plus 16 
percent of the salary rate to cover benefits.
    (ii) For computer searches of records, the Council will charge 
requesters the direct costs of conducting the search. In accordance with 
paragraph (f) of this section, however, the Council will charge certain 
requesters no search fee and certain other requesters are entitled to 
the cost equivalent of two hours of manual search time without charge. 
These direct costs include the costs attributable to the salary of an 
operator/programmer performing a computer search.
    (3) Duplication. The Council will charge duplication fees to all 
requesters, subject to the limitations of paragraph (b)(5) of this 
section. The fee for a paper photocopy of a record (no more than one 
copy of which need be supplied) is 5 cents per page. The Records 
Management Officer will charge the requester for the direct costs, 
including operator time, of making copies produced by computer, such as 
tapes or printouts. The Records Management Officer will charge a 
requester the direct costs of providing other forms of duplication.
    (4) Review. The Council will charge review fees to requesters who 
make a commercial use request. Review fees generally are limited to the 
initial record review, i.e., the review done when the Records Management 
Officer determines whether an exemption applies to a particular record 
at the initial request level. The Council will not charge a requester 
for additional review at the administrative appeal level. Review fees 
consist of the direct costs of conducting the review by the Council 
employee involved, plus 16 percent of the salary rate to cover benefits.
    (5) Limitations on charging fees. (i) The Council will not charge a 
search fee for requests from educational institutions, noncommercial 
scientific institutions, or representatives of the news media.
    (ii) The Council will not charge a search fee or review fee for a 
quarter-hour period unless more than half of that period is required for 
search or review.
    (iii) The Council will not charge a fee to a requester whenever the 
total fee calculated under this paragraph is $25 or less for the 
request.

[[Page 770]]

    (iv) Except for requesters seeking records for a commercial use, the 
Council will provide without charge the first 100 pages of duplication 
(or the cost equivalent) and the first two hours of search.
    (v) The provisions of paragraphs (b)(5)(iii) and (iv) of this 
section work together. This means that for requesters other than those 
seeking records for a commercial use, no fee shall be charged unless the 
cost of search is in excess of two hours plus the cost of duplication in 
excess of 100 pages totals more than $25.
    (vi) No search fees shall be charged to a requester when the Council 
does not comply with the statutory time limits at 5 U.S.C. 552(a)(6) in 
which to respond to a request, unless unusual or exceptional 
circumstances (as those terms are defined by the FOIA) apply to the 
processing of the request.
    (vii) No duplication fees shall be charged to requesters in the fee 
category of a representative of the news media or an educational or 
noncommercial scientific institution when the Council does not comply 
with the statutory time limits at 5 U.S.C. 552(a)(6) in which to respond 
to a request, unless unusual or exceptional circumstances (as those 
terms are defined by the FOIA) apply to the processing of the request.
    (c) Payment procedures. All requesters shall pay the applicable fee 
before the Council sends copies of the requested records, unless the 
Records Management Official grants a fee waiver. Requesters must pay 
fees by check or money order made payable to the ``Treasury of the 
United States.'' Checks and money orders should be mailed to 500 Poydras 
Street, Suite 1117, New Orleans, LA 70130.
    (d) Advance notification of fees. If the estimated charges exceed 
$25, the Records Management Officer shall notify the requester of the 
estimated amount, unless the requester has indicated a willingness to 
pay fees as high as those anticipated. Upon receipt of such notice, the 
requester may confer with the Records Management Officer to reformulate 
the request to lower the costs. Council staff shall suspend processing 
the request until the requester provides the Records Management Officer 
with a written guarantee that the requester will make payment upon 
completion of processing (i.e., upon completion of the search, review 
and duplication, but prior the Council sending copies of the requested 
records to the requester).
    (e) Advance payment. The Records Management Officer shall require 
advance payment of any fee estimated to exceed $250. The Records 
Management Officer also shall require full payment in advance where a 
requester has previously failed to pay a fee in a timely fashion. If an 
advance payment of an estimated fee exceeds the actual total fee by $1 
or more, the Council shall refund the difference to the requester. The 
Council shall suspend the processing of the request and the statutory 
time period for responding to the request until the Records Management 
Officer receives the required payment.
    (f) Categories of uses. The fees assessed depend upon the fee 
category. In determining which category is appropriate, the Records 
Management Officer shall look to the identity of the requester and the 
intended use set forth in the request for records. Where a requester's 
description of the use is insufficient to make a determination, the 
Records Management Officer may seek additional clarification before 
categorizing the request.
    (1) Commercial use requester: The fees for search, duplication, and 
review apply.
    (2) Educational institutions, non-commercial scientific 
institutions, or representatives of the news media requesters: The fees 
for duplication apply. The Council will provide the first 100 pages of 
duplication free of charge.
    (3) All other requesters: The fees for search and duplication apply. 
The Council will provide the first two hours of search time and the 
first 100 pages of duplication free of charge.

------------------------------------------------------------------------
                Category                         Chargeable fees
------------------------------------------------------------------------
(i) Commercial Use Requesters..........  Search, Review, and
                                          Duplication.
(ii) Education and Non-commercial        Duplication (excluding the cost
 Scientific Institution Requesters.       of the first 100 pages).

[[Page 771]]

 
(iii) Representatives of the News Media  Duplication (excluding the cost
                                          of the first 100 pages).
(iv) All Other Requesters..............  Search and Duplication
                                          (excluding the cost of the
                                          first 2 hours of search and
                                          first 100 pages of
                                          duplication).
------------------------------------------------------------------------

    (g) Nonproductive search. The Council may charge fees for search 
even if no responsive documents are found.
    (h) Interest charges. The Records Management Officer may assess 
interest charges on any unpaid bill starting on the 31st calendar day 
following the date the Council sent the bill to the requester. The 
Council will charge interest at the rate prescribed in 31 U.S.C. 3717 on 
fees payable in accordance with this section. The Council will follow 
the provisions of the Debt Collection Act of 1982 (Pub. L. 97-365, 96 
Stat. 1749), as amended, and its administrative procedures, including 
the use of consumer reporting agencies, collection agencies, and offset.
    (i) Aggregated requests. A requester may not file multiple requests 
at the same time solely in order to avoid payment of fees. If the 
Council reasonably believes that a request, or a group of requesters 
acting in concert, is attempting to break down a request into a series 
of requests for the purpose of evading the assessment of fees, the 
Council may aggregate any such requests and charge accordingly. The 
Records Management Officer may reasonably presume that one requester 
making multiple requests on the same topic within a 30-day period has 
done so to avoid fees.
    (j) Waiver or reduction of fees. To seek a waiver, a requester shall 
include the request for waiver or reduction of fees, and the 
justification for such based on the factors set forth in this paragraph, 
with the request for records to which it pertains. If a requester 
requests a waiver or reduction and has not indicated in writing an 
agreement to pay the applicable fees, the time for responding to the 
request for Council records shall not begin until the Records Management 
Officer makes a determination regarding the request for a waiver or 
reduction of fees.
    (1) Records responsive to a request shall be furnished without 
charge, or at a reduced rate below that established in paragraph (b) of 
this section, where the Council determines, after consideration of all 
available information, that the requester has demonstrated that:
    (i) Disclosure of the requested information is in the public 
interest because it is likely to contribute significantly to public 
understanding of the operations or activities of the Government; and
    (ii) Disclosure of the information is not primarily in the 
commercial interest of the requester.
    (2) In deciding whether disclosure of the requested information is 
in the public interest because it is likely to contribute significantly 
to public understanding of the operations or activities of the 
Government, the Council will consider the following factors:
    (i) The subject of the request: Whether the subject of the requested 
records concerns the operations or activities of the Government. The 
subject of the requested records must concern identifiable operations or 
activities of the Federal government, with a connection that is direct 
and clear, not remote or attenuated.
    (ii) The informative value of the information to be disclosed: 
Whether the disclosure is ``likely to contribute'' to an understanding 
of Government operations or activities. The disclosable portions of the 
requested records must be meaningfully informative about government 
operations or activities in order to be ``likely to contribute'' to an 
increased public understanding of those operations or activities. The 
disclosure of information that already is in the public domain, in 
either the same or a substantially identical form, would not be likely 
to contribute to such an understanding.
    (iii) The contribution to an understanding of the subject by the 
public: Whether disclosure of the requested information will contribute 
to the understanding of a reasonably broad audience of persons 
interested in the subject, as opposed to the individual understanding of 
the requester. A requester's expertise in the subject area

[[Page 772]]

as well as his or her ability and intention to effectively convey 
information to the public shall be considered. It shall be presumed that 
a representative of the news media will satisfy this consideration. 
Merely providing information to media sources is insufficient to satisfy 
this consideration.
    (iv) The significance of the contribution to public understanding: 
Whether the disclosure is likely to contribute ``significantly'' to 
public understanding of Government operations or activities. The 
public's understanding of the subject in question prior to disclosure 
must be significantly enhanced by the disclosure.
    (3) To determine whether disclosure of the requested information is 
primarily in the commercial interest of the requester, the Council will 
consider the following factors:
    (i) The existence and magnitude of a commercial interest: Whether 
the requester has a commercial interest that would be furthered by the 
requested disclosure. The Council shall consider any commercial interest 
of the requester (with reference to the definition of ``commercial use 
request'' in Sec.  1850.2(b)), or of any person on whose behalf the 
requester may be acting, that would be furthered by the requested 
disclosure. Requesters shall be given an opportunity to provide 
explanatory information regarding this consideration.
    (ii) The primary interest in disclosure: Whether any identified 
commercial interest of the requester is sufficiently great, in 
comparison with the public interest in disclosure, that disclosure if 
``primarily in the commercial interest of the requester.'' A fee waiver 
or reduction is justified if the public interest standard (paragraph 
(j)(1)(i) of this section) is satisfied and the public interest is 
greater than any identified commercial interest in disclosure. The 
Council shall presume that if a news media requester has satisfied the 
public interest standard, the public interest is the primary interest 
served by disclosure to that requester. Disclosure to data brokers or 
others who merely compile and market Government information for direct 
economic return shall not be presumed to primarily serve the public 
interest.
    (4) A request for a waiver or reduction of fees shall include a 
clear statement of how the request satisfies the criteria set forth in 
paragraphs (j)(2) and (3) of this section, insofar as they apply to each 
request. The burden shall be on the requester to present evidence or 
information in support of a request for a waiver or reduction of fees.
    (5) Where only some of the records to be released satisfy the 
requirements for a fee waiver, a waiver shall be granted for those 
records.
    (6) The Records Management Officer shall make a determination on the 
request for a waiver or reduction of fees and shall notify the requester 
accordingly. A denial may be appealed to the General Counsel in 
accordance with Sec.  1850.7.



Sec.  1850.11  Requests for confidential treatment of business 
information.

    (a) Submission of request. Any submitter of information to the 
Council who desires confidential treatment of business information 
pursuant to 5 U.S.C. 552(b)(4) shall file a request for confidential 
treatment with the Council at the time the information is submitted or 
within a reasonable time after submission. These designations will 
expire ten years after the date of submission unless the submitter 
requests, and provides justification for, a longer period.
    (b) Form of request. Each request for confidential treatment of 
business information shall state in reasonable detail the facts 
supporting the commercial or financial nature of the business 
information and the legal justification under which the business 
information should be protected. Conclusory statements indicating that 
release of the information would cause competitive harm generally are 
not sufficient to justify confidential treatment.
    (c) Designation and separation of confidential material. A submitter 
shall clearly mark all information it considers confidential as 
``PROPRIETARY'' or ``BUSINESS CONFIDENTIAL'' in the submission and shall 
separate information so marked from other information submitted. Failure 
by the submitter to segregate confidential commercial or financial 
information from other material may result in

[[Page 773]]

release of the nonsegregated material to the public without notice to 
the submitter.



Sec.  1850.12  Requests for access to confidential commercial
or financial information.

    (a) Notice to submitters. The Council shall provide a submitter with 
prompt notice of a FOIA request or administrative appeal that seeks its 
business information whenever required under paragraph (b) of this 
section, except as provided in paragraph (e) of this section, in order 
to give the submitter an opportunity under paragraph (c) of this section 
to object to disclosure of any specified portion of that information. 
The notice shall either describe the business information requested or 
include copies of the requested records containing the information. If 
notification of a large number of submitters is required, notification 
may be made by posting or publishing the notice in a place reasonably 
likely to accomplish notification.
    (b) When notice is required. Notice shall be given to the submitter 
whenever:
    (1) The submitter has designated the information in good faith as 
protected from disclosure under FOIA exemption (b)(4); or
    (2) The Council has reason to believe that the information may be 
protected from disclosure under FOIA exemption (b)(4).
    (c) Opportunity to object to disclosure. The Council shall allow a 
submitter seven days from the date of receipt of the written notice 
described in paragraph (a) of this section to provide the Council with a 
statement of any objection to disclosure. The statement must identify 
any portions of the information the submitter requests to be withheld 
under FOIA exemption (b)(4), and describe how each qualifies for 
protection under the exemption: That is, why the information is a trade 
secret, or commercial or financial information that is privileged or 
confidential. If a submitter fails to respond to the notice within the 
time frame specified, the submitter will be considered to have no 
objection to disclosure of the information. Information a submitter 
provides under this paragraph may itself be subject to disclosure under 
the FOIA.
    (d) Notice of intent to disclose. The Council shall consider a 
submitter's objections and specific grounds under the FOIA for 
nondisclosure in deciding whether to disclose business information. If 
the Council decides to disclose business information over a submitter's 
objection, the Council shall give the submitter written notice via 
certified mail, return receipt requested, or similar means, which shall 
include:
    (1) A statement of reason(s) why the submitter's objections to 
disclosure were not sustained;
    (2) A description of the business information to be disclosed; and
    (3) A statement that the Council intends to disclose the information 
seven days from the date the submitter receives the notice.
    (e) Exceptions to notice requirements. The notice requirements of 
paragraphs (a) and (d) of this section shall not apply if:
    (1) The Council determines that the information is exempt and will 
be withheld under a FOIA exemption, other than exemption (b)(4);
    (2) The information has been lawfully published or has been 
officially made available to the public;
    (3) Disclosure of the information is required by statute (other than 
the FOIA) or by a regulation issued in accordance with Executive Order 
12600; or
    (4) The designation made by the submitter under this section or 
Sec.  1850.11 appears obviously frivolous, except that, in such a case, 
the Council shall provide the submitter written notice of any final 
decision to disclose the information seven days from the date the 
submitter receives the notice.
    (f) Notice to requester. The Council shall notify a requester 
whenever it provides the submitter with notice and an opportunity to 
object to disclosure; whenever it notifies the submitter of its intent 
to disclose the requested information; and whenever a submitter files a 
lawsuit to prevent the disclosure of the information.
    (g) Notice of lawsuits. Whenever a requester files a lawsuit seeking 
to compel the disclosure of confidential commercial information, the 
Council shall promptly notify the submitter.

[[Page 774]]



Sec.  1850.13  Classified information.

    In processing a request for information classified under Executive 
Order 13526 or any other Executive Order concerning the classification 
of records, the information shall be reviewed to determine whether it 
should remain classified. Ordinarily the Council or other Federal agency 
that classified the information should conduct the review, except that 
if a record contains information that has been derivatively classified 
by the Council because it contains information classified by another 
agency, the Council shall refer the responsibility for responding to the 
request to the agency that classified the underlying information. 
Information determined to no longer require classification shall not be 
withheld on the basis of FOIA exemption (b)(1) (5 U.S.C. 552(b)(1)), but 
should be reviewed to assess whether any other FOIA exemption should be 
invoked. Appeals involving classified information shall be processed in 
accordance with Sec.  1850.7.



        Subpart B_Production or Disclosure Under the Privacy Act



Sec.  1850.31  Purpose and scope.

    This subpart contains the regulations of the Gulf Coast Ecosystem 
Restoration Council (Council) implementing the Privacy Act of 1974, 5 
U.S.C. 552a. It sets forth the basic responsibilities of the Council 
under the Privacy Act (the Act) and offers guidance to members of the 
public who wish to exercise any of the rights established by the Act 
with regard to records maintained by the Council. Council records that 
are contained in a government-wide system of records established by the 
U.S. Office of Personnel Management (OPM), the General Services 
Administration (GSA), the Merit Systems Protection Board (MSPB), the 
Office of Government Ethics (OGE), Equal Employment Opportunity 
Commission (EEOC) or the Department of Labor (DOL) for which those 
agencies have published systems notices are subject to the publishing 
agency's Privacy Act regulations. Where the government-wide systems 
notices permit access to these records through the employing agency, an 
individual should submit requests for access to, for amendment of or for 
an accounting of disclosures to the Council in accordance with Sec.  
1850.33.



Sec.  1850.32  Definitions.

    (a) For purposes of this subpart, the terms individual, maintain, 
record, and system of records shall have the meanings set forth in 5 
U.S.C. 552a(a).
    (b) Working days are business days and do not include Saturday, 
Sunday, or federal holidays.



Sec.  1850.33  Procedures for requests pertaining to 
individual records in a record system.

    (a) Any person who wishes to be notified if a system of records 
maintained by the Council contains any record pertaining to him or her, 
or to request access to such record or to request an accounting of 
disclosures made of such record, shall submit a written request, either 
in person or by mail, in accordance with the instructions set forth in 
the system notice published in the Federal Register. The request shall 
include:
    (1) The name of the individual making the request;
    (2) The name of the system of records (as set forth in the system 
notice to which the request relates);
    (3) Any other information specified in the system notice;
    (4) When the request is for access to records, a statement 
indicating whether the requester desires to make a personal inspection 
of the records or be supplied with copies by mail; and
    (5) Any additional information required by Sec.  1850.34 for proper 
verification of identity or authority to access the information.
    (b) Requests pertaining to records contained in a system of records 
established by the Council and for which the Council has published a 
system notice should be submitted to the person or office indicated in 
the system notice. Requests pertaining to Council records contained in 
the government-wide systems of records listed below should be submitted 
as follows:
    (1) For systems OPM/GOVT-1 (General Personnel Records), OPM/GOVT-2 
(Employee Performance File System Records), OPM/GOVT-3 (Records of 
Adverse Actions and Actions Based on

[[Page 775]]

Unacceptable Performance), GSA/GOVT-4 (Contracted Travel Services 
Program), OPM/GOVT-5 (Recruiting, Examining and Placement Records), OPM/
GOVT-6 (Personnel Research and Test Validation Records), OPM/GOVT-7 
(Applicant Race, Sex, National Origin, and Disability Status Records), 
OPM/GOVT-9 (Files on Position Classification Appeals, Job Grading 
Appeals and Retained Grade or Pay Appeals), OPM/GOVT-10 (Employee 
Medical File System Records) and DOL/ESA-13 (Office of Workers' 
Compensation Programs, Federal Employees' Compensation File), or any 
other government-wide system of record not specifically listed, to the 
[email protected]]; and
    (2) For systems OGE/GOVT-1 (Executive Branch Public Financial 
Disclosure Reports and Other Ethics Program Records), OGE/GOVT-2 
(Confidential Statements of Employment and Financial Interests) and 
MSPB/GOVT-1 (Appeal and Case Records), to the General Counsel at 
[email protected].
    (c) Any person whose request for access under paragraph (a) of this 
section is denied, may appeal that denial in accordance with Sec.  
1850.39.



Sec.  1850.34  Times, places, and requirements for identification
of individuals making requests.

    (a) If a person submitting a request for access under Sec.  1850.33 
has asked that the Council authorize a personal inspection of records 
pertaining to that person, and the appropriate Council official has 
granted that request, the requester shall present himself or herself at 
the time and place specified in the Council's response or arrange 
another, mutually convenient time with the appropriate Council official.
    (b) Prior to personal inspection of the records, the requester shall 
present sufficient personal identification (e.g., driver's license, 
employee identification card, social security card, credit cards). If 
the requester is unable to provide such identification, the requester 
shall complete and sign in the presence of a Council official a signed 
statement asserting his or her identity and stipulating that he or she 
understands that knowingly or willfully seeking or obtaining access to 
records about another individual under false pretenses is a misdemeanor 
punishable by fine up to $5,000.
    (c) Any person who has requested access under Sec.  1850.3 to 
records through personal inspection, and who wishes to be accompanied by 
another person or persons during this inspection, shall submit a written 
statement authorizing disclosure of the record in such person's or 
persons' presence.
    (d) If an individual submitting a request by mail under Sec.  
1850.33 wishes to have copies furnished by mail, he or she must include 
with the request a signed and notarized statement asserting his or her 
identity and stipulating that he or she understands that knowingly or 
willfully seeking or obtaining access to records about another 
individual under false pretenses is a misdemeanor punishable by fine up 
to $5,000.
    (e) A request filed by the parent of any minor or the legal guardian 
of any incompetent person shall: State the relationship of the requester 
to the individual to whom the record pertains; present sufficient 
identification; and, if not evident from information already available 
to the Council, present appropriate proof of the relationship or 
guardianship.
    (f) A person making a request pursuant to a power of attorney must 
possess a specific power of attorney to make that request.
    (g) No verification of identity will be required where the records 
sought are publicly available under the Freedom of Information Act.



Sec.  1850.35  Disclosure of requested information to individuals.

    (a) Upon receipt of request for notification as to whether the 
Council maintains a record about an individual and/or request for access 
to such record:
    (1) The appropriate Council official shall acknowledge such request 
in writing within 10 working days of receipt of the request. Wherever 
practicable, the acknowledgement should contain the notification and/or 
determination required in paragraph (a)(2) of this section.
    (2) The appropriate Council official shall provide, within 30 
working days

[[Page 776]]

of receipt of the request, written notification to the requester as to 
the existence of the records and/or a determination as to whether or not 
access will be granted. In some cases, such as where records have to be 
recalled from the Federal Records Center, notification and/or a 
determination of access may be delayed. In the event of such a delay, 
the Council official shall inform the requester of this fact, the 
reasons for the delay, and an estimate of the date on which notification 
and/or a determination will be forthcoming.
    (3) If access to a record is granted, the determination shall 
indicate when and where the record will be available for personal 
inspection. If a copy of the record has been requested, the Council 
official shall mail that copy or retain it at the Council to present to 
the individual, upon receipt of a check or money order in an amount 
computed pursuant to Sec.  1850.41.
    (4) When access to a record is to be granted, the appropriate 
Council official will normally provide access within 30 working days of 
receipt of the request unless, for good cause shown, he or she is unable 
to do so, in which case the requester shall be informed within 30 
working days of receipt of the request as to those reasons and when it 
is anticipated that access will be granted.
    (5) The Council shall not deny any request under Sec.  1850.33 
concerning the existence of records about the requester in any system of 
records it maintains, or any request for access to such records, unless 
that system is exempted from the requirements of 5 U.S.C. 552a.
    (6) If the Council receives a request pursuant to Sec.  1850.33 for 
access to records in a system of records it maintains which is so 
exempt, the appropriate Council official shall deny the request.
    (b) Upon request, the appropriate Council official shall make 
available an accounting of disclosures pursuant to 5 U.S.C. 552a(c)(3), 
unless that system is exempted from the requirements of 5 U.S.C. 552a.
    (c) If a request for access to records is denied pursuant to 
paragraph (a) or (b) of this section, the determination shall specify 
the reasons for the denial and advise the individual how to appeal the 
denial in accordance with Sec.  1850.39. All appeals must be submitted 
in writing to the General Counsel at [email protected].
    (d) Nothing in 5 U.S.C. 552a or this subpart allows an individual 
access to any information compiled in reasonable anticipation of a civil 
action or proceeding.



Sec.  1850.36  Special procedures: Medical records.

    In the event the Council receives a request pursuant to Sec.  
1850.33 for access to medical records (including psychological records) 
and the appropriate Council official determines disclosure could be 
harmful to the individual to whom they relate, he or she may refuse to 
disclose the records directly to the requester but shall transmit them 
to a physician designated by that individual.



Sec.  1850.37  Request for correction or amendment to record.

    (a) Any person who wishes to request correction or amendment of any 
record pertaining to him or her that is contained in a system of records 
maintained by the Council, shall submit that request in writing in 
accordance with the instructions set forth in the system notice for that 
system of records. If the request is submitted by mail, the envelope 
should be clearly labeled ``Personal Information Amendment.'' The 
request shall include:
    (1) The name of the individual making the request;
    (2) The name of the system of records as set forth in the system 
notice to which the request relates;
    (3) A description of the nature (e.g., modification, addition or 
deletion) and substance of the correction or amendment requested; and
    (4) Any other information specified in the system notice.
    (b) Any person submitting a request pursuant to paragraph (a) of 
this section shall include sufficient information in support of that 
request to allow the Council to apply the standards set forth in 5 
U.S.C. 552a(e) requiring the Council to maintain accurate, relevant, 
timely, and complete information.
    (c) All requests to amend pertaining to personnel records described 
in

[[Page 777]]

Sec.  1850.33(b) shall conform to the requirements of paragraphs (a) and 
(b) of this section and may be directed to the appropriate officials as 
indicated in Sec.  1850.33(b). Such requests may also be directed to the 
system manager specified in the OPM's systems notices.
    (d) Any person whose request under paragraph (a) of this section is 
denied may appeal that denial in accordance with Sec.  1850.39.



Sec.  1850.38  Council review of request for correction or amendment to record.

    (a) When the Council receives a request for amendment or correction 
under Sec.  1850.37(a), the appropriate Council official shall 
acknowledge that request in writing within 10 working days of receipt. 
He or she shall promptly either:
    (1) Determine to grant all or any portion of a request for 
correction or amendment; and:
    (i) Advise the individual of that determination;
    (ii) Make the requested correction or amendment; and
    (iii) Inform any person or agency outside the Council to whom the 
record has been disclosed, and where an accounting of that disclosure is 
maintained in accordance with 5 U.S.C. 552a(c), of the occurrence and 
substance of the correction or amendments; or
    (2) Inform the requester of the refusal to amend the record in 
accordance with the request; the reason for the refusal; and the 
procedures whereby the requester can appeal the refusal to the General 
Counsel of the Council in accordance with Sec.  1850.39.
    (b) If the Council official informs the requester of the 
determination within the 10-day deadline, a separate acknowledgement is 
not required.
    (c) In conducting the review of a request for correction or 
amendment, the Council official shall be guided by the requirements of 5 
U.S.C. 552a(e).
    (d) In the event that the Council receives a notice of correction or 
amendment from another agency that pertains to records maintained by the 
Council, the Council shall make the appropriate correction or amendment 
to its records and comply with paragraph (a)(1)(iii) of this section.
    (e) Requests for amendment or correction of records maintained in 
the government-wide systems of records listed in Sec.  1850.35(c) shall 
be governed by the appropriate agency's regulations cited in that 
paragraph.



Sec.  1850.39  Appeal of initial adverse agency determination on correction or amendment.

    (a) If a request for correction or amendment of a record in a system 
of records maintained by the Council is denied, the requester may appeal 
the determination in writing to the General Counsel at 
[email protected].
    (b) The General Counsel shall make a final determination with regard 
to an appeal submitted under paragraph (a) of this section not later 
than 30 working days from the date on which the individual requests a 
review, unless for good cause shown, this 30-day period is extended and 
the requester is notified of the reasons for the extension and of the 
estimated date on which a final determination will be made. Such 
extensions will be used only in exceptional circumstances and will not 
normally exceed 30 working days.
    (c) In conducting the review of an appeal submitted under paragraph 
(a) of this section, the General Counsel shall be guided by the 
requirements of 5 U.S.C. 552a(e).
    (d) If the General Counsel determines to grant all or any portion of 
a request on an appeal submitted under paragraph (a) of this section, he 
or she shall so inform the requester, and the appropriate Council 
official shall comply with the procedures set forth in Sec.  
1850.38(a)(1)(ii) and (iii).
    (e) If the General Counsel determines in accordance with paragraphs 
(b) and (c) of this section not to grant all or any portion of a request 
on an appeal submitted under paragraph (a) of this section, he or she 
shall inform the requester:
    (1) Of this determination and the reasons for it;
    (2) Of the requester's right to file a concise statement of reasons 
for disagreement with the determination of the General Counsel;
    (3) That such statements of disagreement will be made available to 
anyone

[[Page 778]]

to whom the record is subsequently disclosed, together with (if the 
General Counsel deems it appropriate) a brief statement summarizing the 
General Counsel's reasons for refusing to amend the record;
    (4) That prior recipients of the disputed record will be provided 
with a copy of the statement of disagreement together with (if the 
General Counsel deems it appropriate) a brief statement of the General 
Counsel's reasons for refusing to amend the record, to the extent that 
an accounting of disclosure is maintained under 5 U.S.C. 552a(c); and
    (5) Of the requester's right to file a civil action in Federal 
district court to seek a review of the determination of the General 
Counsel in accordance with 5 U.S.C. 552a(g).
    (f) The General Counsel shall ensure that any statements of 
disagreement submitted by a requester are made available or distributed 
in accordance with paragraphs (e)(3) and (4) of this section.



Sec.  1850.40  Disclosure of record to person other than the individual to whom it pertains.

    The Counsel shall not disclose any record which is contained in a 
system of records it maintains, by any means of communication to any 
person or to another agency, except pursuant to a written request by, or 
with the prior written consent of the individual to whom the record 
pertains, unless the disclosure is authorized by one or more provisions 
of 5 U.S.C. 552a(b).



Sec.  1850.41  Fees.

    (a) No fee shall be charged for searches necessary to locate 
records. No charge shall be made if the total fees authorized are less 
than $1.00. Fees shall be charged for services rendered under this 
subpart as follows:
    (1) For copies made by photocopy--$0.05 per page (maximum of 10 
copies). For copies prepared by computer, such as tapes or printouts, 
the Council will charge the direct cost incurred by the agency, 
including operator time. For other forms of duplication, the Council 
will charge the actual costs of that duplication.
    (2) For attestation of documents--$25.00 per authenticating 
affidavit or declaration.
    (3) For certification of documents--$50.00 per authenticating 
affidavit or declaration.
    (b) All required fees shall be paid in full prior to issuance of 
requested copies of records. Requesters must pay fees by check or money 
order made payable to the ``Treasury of the United States.''



Sec.  1850.42  Penalties.

    The criminal penalties which have been established for violations of 
the Privacy Act of 1974 are set forth in 5 U.S.C. 552a(i). Penalties are 
applicable to any officer or employee of the Council; to contractors and 
employees of such contractors who enter into contracts with the Council, 
and who are considered to be employees of the Council within the meaning 
of 5 U.S.C. 552a(m); and to any person who knowingly and willfully 
requests or obtains any record concerning an individual from the Council 
under false pretenses.

                       PARTS 1851	1899 [RESERVED]

[[Page 779]]



       CHAPTER IX--FEDERAL PERMITTING IMPROVEMENT STEERING COUNCIL




  --------------------------------------------------------------------
Part                                                                Page
1900            Federal Permitting Improvement..............         781

[[Page 781]]



PART 1900_FEDERAL PERMITTING IMPROVEMENT--Table of Contents



Sec.
1900.1 Definitions.
1900.2 FAST-41 sectors.

    Authority: 42 U.S.C. 4370m et seq.

    Source: 86 FR 1287, Jan. 8, 2021, unless otherwise noted.



Sec.  1900.1  Definitions.

    For the purposes of this part, the following terms shall have the 
meaning indicated:
    FAST-41 means Title 41 of the Fixing America's Surface 
Transportation Act, 42 U.S.C. 4370m et seq.
    Federal Permitting Improvement Steering Council or Permitting 
Council means the Federal agency established pursuant to 42 U.S.C. 
4370m-1(a).
    Mining means the process of extracting ore, minerals, or raw 
materials from the ground. Mining does not include the process of 
extracting oil or natural gas from the ground.



Sec.  1900.2  FAST-41 sectors.

    Pursuant to 42 U.S.C. 4370m(6)(A), the Federal Permitting 
Improvement Steering Council has added the following sectors to the 
statutorily defined list of FAST-41 sectors:
    (a) Mining.
    (b) [Reserved]

[[Page 783]]



                              FINDING AIDS




  --------------------------------------------------------------------

  A list of CFR titles, subtitles, chapters, subchapters and parts and 
an alphabetical list of agencies publishing in the CFR are included in 
the CFR Index and Finding Aids volume to the Code of Federal Regulations 
which is published separately and revised annually.


  Table of CFR Titles and Chapters
  Alphabetical List of Agencies Appearing in the CFR
  List of CFR Sections Affected

[[Page 785]]



                    Table of CFR Titles and Chapters




                      (Revised as of July 1, 2023)

                      Title 1--General Provisions

         I  Administrative Committee of the Federal Register 
                (Parts 1--49)
        II  Office of the Federal Register (Parts 50--299)
       III  Administrative Conference of the United States (Parts 
                300--399)
        IV  Miscellaneous Agencies (Parts 400--599)
        VI  National Capital Planning Commission (Parts 600--699)

                    Title 2--Grants and Agreements

            Subtitle A--Office of Management and Budget Guidance 
                for Grants and Agreements
         I  Office of Management and Budget Governmentwide 
                Guidance for Grants and Agreements (Parts 2--199)
        II  Office of Management and Budget Guidance (Parts 200--
                299)
            Subtitle B--Federal Agency Regulations for Grants and 
                Agreements
       III  Department of Health and Human Services (Parts 300--
                399)
        IV  Department of Agriculture (Parts 400--499)
        VI  Department of State (Parts 600--699)
       VII  Agency for International Development (Parts 700--799)
      VIII  Department of Veterans Affairs (Parts 800--899)
        IX  Department of Energy (Parts 900--999)
         X  Department of the Treasury (Parts 1000--1099)
        XI  Department of Defense (Parts 1100--1199)
       XII  Department of Transportation (Parts 1200--1299)
      XIII  Department of Commerce (Parts 1300--1399)
       XIV  Department of the Interior (Parts 1400--1499)
        XV  Environmental Protection Agency (Parts 1500--1599)
     XVIII  National Aeronautics and Space Administration (Parts 
                1800--1899)
        XX  United States Nuclear Regulatory Commission (Parts 
                2000--2099)
      XXII  Corporation for National and Community Service (Parts 
                2200--2299)
     XXIII  Social Security Administration (Parts 2300--2399)
      XXIV  Department of Housing and Urban Development (Parts 
                2400--2499)
       XXV  National Science Foundation (Parts 2500--2599)
      XXVI  National Archives and Records Administration (Parts 
                2600--2699)

[[Page 786]]

     XXVII  Small Business Administration (Parts 2700--2799)
    XXVIII  Department of Justice (Parts 2800--2899)
      XXIX  Department of Labor (Parts 2900--2999)
       XXX  Department of Homeland Security (Parts 3000--3099)
      XXXI  Institute of Museum and Library Services (Parts 3100--
                3199)
     XXXII  National Endowment for the Arts (Parts 3200--3299)
    XXXIII  National Endowment for the Humanities (Parts 3300--
                3399)
     XXXIV  Department of Education (Parts 3400--3499)
      XXXV  Export-Import Bank of the United States (Parts 3500--
                3599)
     XXXVI  Office of National Drug Control Policy, Executive 
                Office of the President (Parts 3600--3699)
    XXXVII  Peace Corps (Parts 3700--3799)
     LVIII  Election Assistance Commission (Parts 5800--5899)
       LIX  Gulf Coast Ecosystem Restoration Council (Parts 5900--
                5999)
        LX  Federal Communications Commission (Parts 6000--6099)

                        Title 3--The President

         I  Executive Office of the President (Parts 100--199)

                           Title 4--Accounts

         I  Government Accountability Office (Parts 1--199)

                   Title 5--Administrative Personnel

         I  Office of Personnel Management (Parts 1--1199)
        II  Merit Systems Protection Board (Parts 1200--1299)
       III  Office of Management and Budget (Parts 1300--1399)
        IV  Office of Personnel Management and Office of the 
                Director of National Intelligence (Parts 1400--
                1499)
         V  The International Organizations Employees Loyalty 
                Board (Parts 1500--1599)
        VI  Federal Retirement Thrift Investment Board (Parts 
                1600--1699)
      VIII  Office of Special Counsel (Parts 1800--1899)
        IX  Appalachian Regional Commission (Parts 1900--1999)
        XI  Armed Forces Retirement Home (Parts 2100--2199)
       XIV  Federal Labor Relations Authority, General Counsel of 
                the Federal Labor Relations Authority and Federal 
                Service Impasses Panel (Parts 2400--2499)
       XVI  Office of Government Ethics (Parts 2600--2699)
       XXI  Department of the Treasury (Parts 3100--3199)
      XXII  Federal Deposit Insurance Corporation (Parts 3200--
                3299)
     XXIII  Department of Energy (Parts 3300--3399)
      XXIV  Federal Energy Regulatory Commission (Parts 3400--
                3499)
       XXV  Department of the Interior (Parts 3500--3599)

[[Page 787]]

      XXVI  Department of Defense (Parts 3600--3699)
    XXVIII  Department of Justice (Parts 3800--3899)
      XXIX  Federal Communications Commission (Parts 3900--3999)
       XXX  Farm Credit System Insurance Corporation (Parts 4000--
                4099)
      XXXI  Farm Credit Administration (Parts 4100--4199)
    XXXIII  U.S. International Development Finance Corporation 
                (Parts 4300--4399)
     XXXIV  Securities and Exchange Commission (Parts 4400--4499)
      XXXV  Office of Personnel Management (Parts 4500--4599)
     XXXVI  Department of Homeland Security (Parts 4600--4699)
    XXXVII  Federal Election Commission (Parts 4700--4799)
        XL  Interstate Commerce Commission (Parts 5000--5099)
       XLI  Commodity Futures Trading Commission (Parts 5100--
                5199)
      XLII  Department of Labor (Parts 5200--5299)
     XLIII  National Science Foundation (Parts 5300--5399)
       XLV  Department of Health and Human Services (Parts 5500--
                5599)
      XLVI  Postal Rate Commission (Parts 5600--5699)
     XLVII  Federal Trade Commission (Parts 5700--5799)
    XLVIII  Nuclear Regulatory Commission (Parts 5800--5899)
      XLIX  Federal Labor Relations Authority (Parts 5900--5999)
         L  Department of Transportation (Parts 6000--6099)
       LII  Export-Import Bank of the United States (Parts 6200--
                6299)
      LIII  Department of Education (Parts 6300--6399)
       LIV  Environmental Protection Agency (Parts 6400--6499)
        LV  National Endowment for the Arts (Parts 6500--6599)
       LVI  National Endowment for the Humanities (Parts 6600--
                6699)
      LVII  General Services Administration (Parts 6700--6799)
     LVIII  Board of Governors of the Federal Reserve System 
                (Parts 6800--6899)
       LIX  National Aeronautics and Space Administration (Parts 
                6900--6999)
        LX  United States Postal Service (Parts 7000--7099)
       LXI  National Labor Relations Board (Parts 7100--7199)
      LXII  Equal Employment Opportunity Commission (Parts 7200--
                7299)
     LXIII  Inter-American Foundation (Parts 7300--7399)
      LXIV  Merit Systems Protection Board (Parts 7400--7499)
       LXV  Department of Housing and Urban Development (Parts 
                7500--7599)
      LXVI  National Archives and Records Administration (Parts 
                7600--7699)
     LXVII  Institute of Museum and Library Services (Parts 7700--
                7799)
    LXVIII  Commission on Civil Rights (Parts 7800--7899)
      LXIX  Tennessee Valley Authority (Parts 7900--7999)
       LXX  Court Services and Offender Supervision Agency for the 
                District of Columbia (Parts 8000--8099)
      LXXI  Consumer Product Safety Commission (Parts 8100--8199)

[[Page 788]]

    LXXIII  Department of Agriculture (Parts 8300--8399)
     LXXIV  Federal Mine Safety and Health Review Commission 
                (Parts 8400--8499)
     LXXVI  Federal Retirement Thrift Investment Board (Parts 
                8600--8699)
    LXXVII  Office of Management and Budget (Parts 8700--8799)
      LXXX  Federal Housing Finance Agency (Parts 9000--9099)
   LXXXIII  Special Inspector General for Afghanistan 
                Reconstruction (Parts 9300--9399)
    LXXXIV  Bureau of Consumer Financial Protection (Parts 9400--
                9499)
    LXXXVI  National Credit Union Administration (Parts 9600--
                9699)
     XCVII  Department of Homeland Security Human Resources 
                Management System (Department of Homeland 
                Security--Office of Personnel Management) (Parts 
                9700--9799)
    XCVIII  Council of the Inspectors General on Integrity and 
                Efficiency (Parts 9800--9899)
      XCIX  Military Compensation and Retirement Modernization 
                Commission (Parts 9900--9999)
         C  National Council on Disability (Parts 10000--10049)
        CI  National Mediation Board (Parts 10100--10199)
       CII  U.S. Office of Special Counsel (Parts 10200--10299)
       CIV  Office of the Intellectual Property Enforcement 
                Coordinator (Part 10400--10499)

                      Title 6--Domestic Security

         I  Department of Homeland Security, Office of the 
                Secretary (Parts 1--199)
         X  Privacy and Civil Liberties Oversight Board (Parts 
                1000--1099)

                         Title 7--Agriculture

            Subtitle A--Office of the Secretary of Agriculture 
                (Parts 0--26)
            Subtitle B--Regulations of the Department of 
                Agriculture
         I  Agricultural Marketing Service (Standards, 
                Inspections, Marketing Practices), Department of 
                Agriculture (Parts 27--209)
        II  Food and Nutrition Service, Department of Agriculture 
                (Parts 210--299)
       III  Animal and Plant Health Inspection Service, Department 
                of Agriculture (Parts 300--399)
        IV  Federal Crop Insurance Corporation, Department of 
                Agriculture (Parts 400--499)
         V  Agricultural Research Service, Department of 
                Agriculture (Parts 500--599)
        VI  Natural Resources Conservation Service, Department of 
                Agriculture (Parts 600--699)
       VII  Farm Service Agency, Department of Agriculture (Parts 
                700--799)

[[Page 789]]

      VIII  Agricultural Marketing Service (Federal Grain 
                Inspection Service, Fair Trade Practices Program), 
                Department of Agriculture (Parts 800--899)
        IX  Agricultural Marketing Service (Marketing Agreements 
                and Orders; Fruits, Vegetables, Nuts), Department 
                of Agriculture (Parts 900--999)
         X  Agricultural Marketing Service (Marketing Agreements 
                and Orders; Milk), Department of Agriculture 
                (Parts 1000--1199)
        XI  Agricultural Marketing Service (Marketing Agreements 
                and Orders; Miscellaneous Commodities), Department 
                of Agriculture (Parts 1200--1299)
       XIV  Commodity Credit Corporation, Department of 
                Agriculture (Parts 1400--1499)
        XV  Foreign Agricultural Service, Department of 
                Agriculture (Parts 1500--1599)
       XVI  [Reserved]
      XVII  Rural Utilities Service, Department of Agriculture 
                (Parts 1700--1799)
     XVIII  Rural Housing Service, Rural Business-Cooperative 
                Service, Rural Utilities Service, and Farm Service 
                Agency, Department of Agriculture (Parts 1800--
                2099)
        XX  [Reserved]
       XXV  Office of Advocacy and Outreach, Department of 
                Agriculture (Parts 2500--2599)
      XXVI  Office of Inspector General, Department of Agriculture 
                (Parts 2600--2699)
     XXVII  Office of Information Resources Management, Department 
                of Agriculture (Parts 2700--2799)
    XXVIII  Office of Operations, Department of Agriculture (Parts 
                2800--2899)
      XXIX  Office of Energy Policy and New Uses, Department of 
                Agriculture (Parts 2900--2999)
       XXX  Office of the Chief Financial Officer, Department of 
                Agriculture (Parts 3000--3099)
      XXXI  Office of Environmental Quality, Department of 
                Agriculture (Parts 3100--3199)
     XXXII  Office of Procurement and Property Management, 
                Department of Agriculture (Parts 3200--3299)
    XXXIII  Office of Transportation, Department of Agriculture 
                (Parts 3300--3399)
     XXXIV  National Institute of Food and Agriculture (Parts 
                3400--3499)
      XXXV  Rural Housing Service, Department of Agriculture 
                (Parts 3500--3599)
     XXXVI  National Agricultural Statistics Service, Department 
                of Agriculture (Parts 3600--3699)
    XXXVII  Economic Research Service, Department of Agriculture 
                (Parts 3700--3799)
   XXXVIII  World Agricultural Outlook Board, Department of 
                Agriculture (Parts 3800--3899)
       XLI  [Reserved]

[[Page 790]]

      XLII  Rural Business-Cooperative Service and Rural Utilities 
                Service, Department of Agriculture (Parts 4200--
                4299)
         L  Rural Business-Cooperative Service, and Rural 
                Utilities Service, Department of Agriculture 
                (Parts 5000--5099)

                    Title 8--Aliens and Nationality

         I  Department of Homeland Security (Parts 1--499)
         V  Executive Office for Immigration Review, Department of 
                Justice (Parts 1000--1399)

                 Title 9--Animals and Animal Products

         I  Animal and Plant Health Inspection Service, Department 
                of Agriculture (Parts 1--199)
        II  Agricultural Marketing Service (Fair Trade Practices 
                Program), Department of Agriculture (Parts 200--
                299)
       III  Food Safety and Inspection Service, Department of 
                Agriculture (Parts 300--599)

                           Title 10--Energy

         I  Nuclear Regulatory Commission (Parts 0--199)
        II  Department of Energy (Parts 200--699)
       III  Department of Energy (Parts 700--999)
         X  Department of Energy (General Provisions) (Parts 
                1000--1099)
      XIII  Nuclear Waste Technical Review Board (Parts 1300--
                1399)
      XVII  Defense Nuclear Facilities Safety Board (Parts 1700--
                1799)
     XVIII  Northeast Interstate Low-Level Radioactive Waste 
                Commission (Parts 1800--1899)

                      Title 11--Federal Elections

         I  Federal Election Commission (Parts 1--9099)
        II  Election Assistance Commission (Parts 9400--9499)

                      Title 12--Banks and Banking

         I  Comptroller of the Currency, Department of the 
                Treasury (Parts 1--199)
        II  Federal Reserve System (Parts 200--299)
       III  Federal Deposit Insurance Corporation (Parts 300--399)
        IV  Export-Import Bank of the United States (Parts 400--
                499)
         V  [Reserved]
        VI  Farm Credit Administration (Parts 600--699)
       VII  National Credit Union Administration (Parts 700--799)
      VIII  Federal Financing Bank (Parts 800--899)
        IX  (Parts 900--999)[Reserved]

[[Page 791]]

         X  Consumer Financial Protection Bureau (Parts 1000--
                1099)
        XI  Federal Financial Institutions Examination Council 
                (Parts 1100--1199)
       XII  Federal Housing Finance Agency (Parts 1200--1299)
      XIII  Financial Stability Oversight Council (Parts 1300--
                1399)
       XIV  Farm Credit System Insurance Corporation (Parts 1400--
                1499)
        XV  Department of the Treasury (Parts 1500--1599)
       XVI  Office of Financial Research, Department of the 
                Treasury (Parts 1600--1699)
      XVII  Office of Federal Housing Enterprise Oversight, 
                Department of Housing and Urban Development (Parts 
                1700--1799)
     XVIII  Community Development Financial Institutions Fund, 
                Department of the Treasury (Parts 1800--1899)

               Title 13--Business Credit and Assistance

         I  Small Business Administration (Parts 1--199)
       III  Economic Development Administration, Department of 
                Commerce (Parts 300--399)
        IV  Emergency Steel Guarantee Loan Board (Parts 400--499)
         V  Emergency Oil and Gas Guaranteed Loan Board (Parts 
                500--599)

                    Title 14--Aeronautics and Space

         I  Federal Aviation Administration, Department of 
                Transportation (Parts 1--199)
        II  Office of the Secretary, Department of Transportation 
                (Aviation Proceedings) (Parts 200--399)
       III  Commercial Space Transportation, Federal Aviation 
                Administration, Department of Transportation 
                (Parts 400--1199)
         V  National Aeronautics and Space Administration (Parts 
                1200--1299)
        VI  Air Transportation System Stabilization (Parts 1300--
                1399)

                 Title 15--Commerce and Foreign Trade

            Subtitle A--Office of the Secretary of Commerce (Parts 
                0--29)
            Subtitle B--Regulations Relating to Commerce and 
                Foreign Trade
         I  Bureau of the Census, Department of Commerce (Parts 
                30--199)
        II  National Institute of Standards and Technology, 
                Department of Commerce (Parts 200--299)
       III  International Trade Administration, Department of 
                Commerce (Parts 300--399)
        IV  Foreign-Trade Zones Board, Department of Commerce 
                (Parts 400--499)
       VII  Bureau of Industry and Security, Department of 
                Commerce (Parts 700--799)

[[Page 792]]

      VIII  Bureau of Economic Analysis, Department of Commerce 
                (Parts 800--899)
        IX  National Oceanic and Atmospheric Administration, 
                Department of Commerce (Parts 900--999)
        XI  National Technical Information Service, Department of 
                Commerce (Parts 1100--1199)
      XIII  East-West Foreign Trade Board (Parts 1300--1399)
       XIV  Minority Business Development Agency (Parts 1400--
                1499)
        XV  Office of the Under-Secretary for Economic Affairs, 
                Department of Commerce (Parts 1500--1599)
            Subtitle C--Regulations Relating to Foreign Trade 
                Agreements
        XX  Office of the United States Trade Representative 
                (Parts 2000--2099)
            Subtitle D--Regulations Relating to Telecommunications 
                and Information
     XXIII  National Telecommunications and Information 
                Administration, Department of Commerce (Parts 
                2300--2399) [Reserved]

                    Title 16--Commercial Practices

         I  Federal Trade Commission (Parts 0--999)
        II  Consumer Product Safety Commission (Parts 1000--1799)

             Title 17--Commodity and Securities Exchanges

         I  Commodity Futures Trading Commission (Parts 1--199)
        II  Securities and Exchange Commission (Parts 200--399)
        IV  Department of the Treasury (Parts 400--499)

          Title 18--Conservation of Power and Water Resources

         I  Federal Energy Regulatory Commission, Department of 
                Energy (Parts 1--399)
       III  Delaware River Basin Commission (Parts 400--499)
        VI  Water Resources Council (Parts 700--799)
      VIII  Susquehanna River Basin Commission (Parts 800--899)
      XIII  Tennessee Valley Authority (Parts 1300--1399)

                       Title 19--Customs Duties

         I  U.S. Customs and Border Protection, Department of 
                Homeland Security; Department of the Treasury 
                (Parts 0--199)
        II  United States International Trade Commission (Parts 
                200--299)
       III  International Trade Administration, Department of 
                Commerce (Parts 300--399)
        IV  U.S. Immigration and Customs Enforcement, Department 
                of Homeland Security (Parts 400--599) [Reserved]

[[Page 793]]

                     Title 20--Employees' Benefits

         I  Office of Workers' Compensation Programs, Department 
                of Labor (Parts 1--199)
        II  Railroad Retirement Board (Parts 200--399)
       III  Social Security Administration (Parts 400--499)
        IV  Employees' Compensation Appeals Board, Department of 
                Labor (Parts 500--599)
         V  Employment and Training Administration, Department of 
                Labor (Parts 600--699)
        VI  Office of Workers' Compensation Programs, Department 
                of Labor (Parts 700--799)
       VII  Benefits Review Board, Department of Labor (Parts 
                800--899)
      VIII  Joint Board for the Enrollment of Actuaries (Parts 
                900--999)
        IX  Office of the Assistant Secretary for Veterans' 
                Employment and Training Service, Department of 
                Labor (Parts 1000--1099)

                       Title 21--Food and Drugs

         I  Food and Drug Administration, Department of Health and 
                Human Services (Parts 1--1299)
        II  Drug Enforcement Administration, Department of Justice 
                (Parts 1300--1399)
       III  Office of National Drug Control Policy (Parts 1400--
                1499)

                      Title 22--Foreign Relations

         I  Department of State (Parts 1--199)
        II  Agency for International Development (Parts 200--299)
       III  Peace Corps (Parts 300--399)
        IV  International Joint Commission, United States and 
                Canada (Parts 400--499)
         V  United States Agency for Global Media (Parts 500--599)
       VII  U.S. International Development Finance Corporation 
                (Parts 700--799)
        IX  Foreign Service Grievance Board (Parts 900--999)
         X  Inter-American Foundation (Parts 1000--1099)
        XI  International Boundary and Water Commission, United 
                States and Mexico, United States Section (Parts 
                1100--1199)
       XII  United States International Development Cooperation 
                Agency (Parts 1200--1299)
      XIII  Millennium Challenge Corporation (Parts 1300--1399)
       XIV  Foreign Service Labor Relations Board; Federal Labor 
                Relations Authority; General Counsel of the 
                Federal Labor Relations Authority; and the Foreign 
                Service Impasse Disputes Panel (Parts 1400--1499)
        XV  African Development Foundation (Parts 1500--1599)
       XVI  Japan-United States Friendship Commission (Parts 
                1600--1699)
      XVII  United States Institute of Peace (Parts 1700--1799)

[[Page 794]]

                          Title 23--Highways

         I  Federal Highway Administration, Department of 
                Transportation (Parts 1--999)
        II  National Highway Traffic Safety Administration and 
                Federal Highway Administration, Department of 
                Transportation (Parts 1200--1299)
       III  National Highway Traffic Safety Administration, 
                Department of Transportation (Parts 1300--1399)

                Title 24--Housing and Urban Development

            Subtitle A--Office of the Secretary, Department of 
                Housing and Urban Development (Parts 0--99)
            Subtitle B--Regulations Relating to Housing and Urban 
                Development
         I  Office of Assistant Secretary for Equal Opportunity, 
                Department of Housing and Urban Development (Parts 
                100--199)
        II  Office of Assistant Secretary for Housing-Federal 
                Housing Commissioner, Department of Housing and 
                Urban Development (Parts 200--299)
       III  Government National Mortgage Association, Department 
                of Housing and Urban Development (Parts 300--399)
        IV  Office of Housing and Office of Multifamily Housing 
                Assistance Restructuring, Department of Housing 
                and Urban Development (Parts 400--499)
         V  Office of Assistant Secretary for Community Planning 
                and Development, Department of Housing and Urban 
                Development (Parts 500--599)
        VI  Office of Assistant Secretary for Community Planning 
                and Development, Department of Housing and Urban 
                Development (Parts 600--699) [Reserved]
       VII  Office of the Secretary, Department of Housing and 
                Urban Development (Housing Assistance Programs and 
                Public and Indian Housing Programs) (Parts 700--
                799)
      VIII  Office of the Assistant Secretary for Housing--Federal 
                Housing Commissioner, Department of Housing and 
                Urban Development (Section 8 Housing Assistance 
                Programs, Section 202 Direct Loan Program, Section 
                202 Supportive Housing for the Elderly Program and 
                Section 811 Supportive Housing for Persons With 
                Disabilities Program) (Parts 800--899)
        IX  Office of Assistant Secretary for Public and Indian 
                Housing, Department of Housing and Urban 
                Development (Parts 900--1699)
         X  Office of Assistant Secretary for Housing--Federal 
                Housing Commissioner, Department of Housing and 
                Urban Development (Interstate Land Sales 
                Registration Program) (Parts 1700--1799) 
                [Reserved]
       XII  Office of Inspector General, Department of Housing and 
                Urban Development (Parts 2000--2099)
        XV  Emergency Mortgage Insurance and Loan Programs, 
                Department of Housing and Urban Development (Parts 
                2700--2799) [Reserved]

[[Page 795]]

        XX  Office of Assistant Secretary for Housing--Federal 
                Housing Commissioner, Department of Housing and 
                Urban Development (Parts 3200--3899)
      XXIV  Board of Directors of the HOPE for Homeowners Program 
                (Parts 4000--4099) [Reserved]
       XXV  Neighborhood Reinvestment Corporation (Parts 4100--
                4199)

                           Title 25--Indians

         I  Bureau of Indian Affairs, Department of the Interior 
                (Parts 1--299)
        II  Indian Arts and Crafts Board, Department of the 
                Interior (Parts 300--399)
       III  National Indian Gaming Commission, Department of the 
                Interior (Parts 500--599)
        IV  Office of Navajo and Hopi Indian Relocation (Parts 
                700--899)
         V  Bureau of Indian Affairs, Department of the Interior, 
                and Indian Health Service, Department of Health 
                and Human Services (Part 900--999)
        VI  Office of the Assistant Secretary, Indian Affairs, 
                Department of the Interior (Parts 1000--1199)
       VII  Office of the Special Trustee for American Indians, 
                Department of the Interior (Parts 1200--1299)

                      Title 26--Internal Revenue

         I  Internal Revenue Service, Department of the Treasury 
                (Parts 1--End)

           Title 27--Alcohol, Tobacco Products and Firearms

         I  Alcohol and Tobacco Tax and Trade Bureau, Department 
                of the Treasury (Parts 1--399)
        II  Bureau of Alcohol, Tobacco, Firearms, and Explosives, 
                Department of Justice (Parts 400--799)

                   Title 28--Judicial Administration

         I  Department of Justice (Parts 0--299)
       III  Federal Prison Industries, Inc., Department of Justice 
                (Parts 300--399)
         V  Bureau of Prisons, Department of Justice (Parts 500--
                599)
        VI  Offices of Independent Counsel, Department of Justice 
                (Parts 600--699)
       VII  Office of Independent Counsel (Parts 700--799)
      VIII  Court Services and Offender Supervision Agency for the 
                District of Columbia (Parts 800--899)
        IX  National Crime Prevention and Privacy Compact Council 
                (Parts 900--999)

[[Page 796]]

        XI  Department of Justice and Department of State (Parts 
                1100--1199)

                            Title 29--Labor

            Subtitle A--Office of the Secretary of Labor (Parts 
                0--99)
            Subtitle B--Regulations Relating to Labor
         I  National Labor Relations Board (Parts 100--199)
        II  Office of Labor-Management Standards, Department of 
                Labor (Parts 200--299)
       III  National Railroad Adjustment Board (Parts 300--399)
        IV  Office of Labor-Management Standards, Department of 
                Labor (Parts 400--499)
         V  Wage and Hour Division, Department of Labor (Parts 
                500--899)
        IX  Construction Industry Collective Bargaining Commission 
                (Parts 900--999)
         X  National Mediation Board (Parts 1200--1299)
       XII  Federal Mediation and Conciliation Service (Parts 
                1400--1499)
       XIV  Equal Employment Opportunity Commission (Parts 1600--
                1699)
      XVII  Occupational Safety and Health Administration, 
                Department of Labor (Parts 1900--1999)
        XX  Occupational Safety and Health Review Commission 
                (Parts 2200--2499)
       XXV  Employee Benefits Security Administration, Department 
                of Labor (Parts 2500--2599)
     XXVII  Federal Mine Safety and Health Review Commission 
                (Parts 2700--2799)
        XL  Pension Benefit Guaranty Corporation (Parts 4000--
                4999)

                      Title 30--Mineral Resources

         I  Mine Safety and Health Administration, Department of 
                Labor (Parts 1--199)
        II  Bureau of Safety and Environmental Enforcement, 
                Department of the Interior (Parts 200--299)
        IV  Geological Survey, Department of the Interior (Parts 
                400--499)
         V  Bureau of Ocean Energy Management, Department of the 
                Interior (Parts 500--599)
       VII  Office of Surface Mining Reclamation and Enforcement, 
                Department of the Interior (Parts 700--999)
       XII  Office of Natural Resources Revenue, Department of the 
                Interior (Parts 1200--1299)

                 Title 31--Money and Finance: Treasury

            Subtitle A--Office of the Secretary of the Treasury 
                (Parts 0--50)
            Subtitle B--Regulations Relating to Money and Finance

[[Page 797]]

         I  Monetary Offices, Department of the Treasury (Parts 
                51--199)
        II  Fiscal Service, Department of the Treasury (Parts 
                200--399)
        IV  Secret Service, Department of the Treasury (Parts 
                400--499)
         V  Office of Foreign Assets Control, Department of the 
                Treasury (Parts 500--599)
        VI  Bureau of Engraving and Printing, Department of the 
                Treasury (Parts 600--699)
       VII  Federal Law Enforcement Training Center, Department of 
                the Treasury (Parts 700--799)
      VIII  Office of Investment Security, Department of the 
                Treasury (Parts 800--899)
        IX  Federal Claims Collection Standards (Department of the 
                Treasury--Department of Justice) (Parts 900--999)
         X  Financial Crimes Enforcement Network, Department of 
                the Treasury (Parts 1000--1099)

                      Title 32--National Defense

            Subtitle A--Department of Defense
         I  Office of the Secretary of Defense (Parts 1--399)
         V  Department of the Army (Parts 400--699)
        VI  Department of the Navy (Parts 700--799)
       VII  Department of the Air Force (Parts 800--1099)
            Subtitle B--Other Regulations Relating to National 
                Defense
       XII  Department of Defense, Defense Logistics Agency (Parts 
                1200--1299)
       XVI  Selective Service System (Parts 1600--1699)
      XVII  Office of the Director of National Intelligence (Parts 
                1700--1799)
     XVIII  National Counterintelligence Center (Parts 1800--1899)
       XIX  Central Intelligence Agency (Parts 1900--1999)
        XX  Information Security Oversight Office, National 
                Archives and Records Administration (Parts 2000--
                2099)
       XXI  National Security Council (Parts 2100--2199)
      XXIV  Office of Science and Technology Policy (Parts 2400--
                2499)
     XXVII  Office for Micronesian Status Negotiations (Parts 
                2700--2799)
    XXVIII  Office of the Vice President of the United States 
                (Parts 2800--2899)

               Title 33--Navigation and Navigable Waters

         I  Coast Guard, Department of Homeland Security (Parts 
                1--199)
        II  Corps of Engineers, Department of the Army, Department 
                of Defense (Parts 200--399)
        IV  Great Lakes St. Lawrence Seaway Development 
                Corporation, Department of Transportation (Parts 
                400--499)

[[Page 798]]

                          Title 34--Education

            Subtitle A--Office of the Secretary, Department of 
                Education (Parts 1--99)
            Subtitle B--Regulations of the Offices of the 
                Department of Education
         I  Office for Civil Rights, Department of Education 
                (Parts 100--199)
        II  Office of Elementary and Secondary Education, 
                Department of Education (Parts 200--299)
       III  Office of Special Education and Rehabilitative 
                Services, Department of Education (Parts 300--399)
        IV  Office of Career, Technical, and Adult Education, 
                Department of Education (Parts 400--499)
         V  Office of Bilingual Education and Minority Languages 
                Affairs, Department of Education (Parts 500--599) 
                [Reserved]
        VI  Office of Postsecondary Education, Department of 
                Education (Parts 600--699)
       VII  Office of Educational Research and Improvement, 
                Department of Education (Parts 700--799) 
                [Reserved]
            Subtitle C--Regulations Relating to Education
        XI  [Reserved]
       XII  National Council on Disability (Parts 1200--1299)

                          Title 35 [Reserved]

             Title 36--Parks, Forests, and Public Property

         I  National Park Service, Department of the Interior 
                (Parts 1--199)
        II  Forest Service, Department of Agriculture (Parts 200--
                299)
       III  Corps of Engineers, Department of the Army (Parts 
                300--399)
        IV  American Battle Monuments Commission (Parts 400--499)
         V  Smithsonian Institution (Parts 500--599)
        VI  [Reserved]
       VII  Library of Congress (Parts 700--799)
      VIII  Advisory Council on Historic Preservation (Parts 800--
                899)
        IX  Pennsylvania Avenue Development Corporation (Parts 
                900--999)
         X  Presidio Trust (Parts 1000--1099)
        XI  Architectural and Transportation Barriers Compliance 
                Board (Parts 1100--1199)
       XII  National Archives and Records Administration (Parts 
                1200--1299)
        XV  Oklahoma City National Memorial Trust (Parts 1500--
                1599)
       XVI  Morris K. Udall Scholarship and Excellence in National 
                Environmental Policy Foundation (Parts 1600--1699)

             Title 37--Patents, Trademarks, and Copyrights

         I  United States Patent and Trademark Office, Department 
                of Commerce (Parts 1--199)
        II  U.S. Copyright Office, Library of Congress (Parts 
                200--299)

[[Page 799]]

       III  Copyright Royalty Board, Library of Congress (Parts 
                300--399)
        IV  National Institute of Standards and Technology, 
                Department of Commerce (Parts 400--599)

           Title 38--Pensions, Bonuses, and Veterans' Relief

         I  Department of Veterans Affairs (Parts 0--199)
        II  Armed Forces Retirement Home (Parts 200--299)

                       Title 39--Postal Service

         I  United States Postal Service (Parts 1--999)
       III  Postal Regulatory Commission (Parts 3000--3099)

                  Title 40--Protection of Environment

         I  Environmental Protection Agency (Parts 1--1099)
        IV  Environmental Protection Agency and Department of 
                Justice (Parts 1400--1499)
         V  Council on Environmental Quality (Parts 1500--1599)
        VI  Chemical Safety and Hazard Investigation Board (Parts 
                1600--1699)
       VII  Environmental Protection Agency and Department of 
                Defense; Uniform National Discharge Standards for 
                Vessels of the Armed Forces (Parts 1700--1799)
      VIII  Gulf Coast Ecosystem Restoration Council (Parts 1800--
                1899)
        IX  Federal Permitting Improvement Steering Council (Part 
                1900)

          Title 41--Public Contracts and Property Management

            Subtitle A--Federal Procurement Regulations System 
                [Note]
            Subtitle B--Other Provisions Relating to Public 
                Contracts
        50  Public Contracts, Department of Labor (Parts 50-1--50-
                999)
        51  Committee for Purchase From People Who Are Blind or 
                Severely Disabled (Parts 51-1--51-99)
        60  Office of Federal Contract Compliance Programs, Equal 
                Employment Opportunity, Department of Labor (Parts 
                60-1--60-999)
        61  Office of the Assistant Secretary for Veterans' 
                Employment and Training Service, Department of 
                Labor (Parts 61-1--61-999)
   62--100  [Reserved]
            Subtitle C--Federal Property Management Regulations 
                System
       101  Federal Property Management Regulations (Parts 101-1--
                101-99)
       102  Federal Management Regulation (Parts 102-1--102-299)
  103--104  (Parts 103-001--104-099) [Reserved]
       105  General Services Administration (Parts 105-1--105-999)

[[Page 800]]

       109  Department of Energy Property Management Regulations 
                (Parts 109-1--109-99)
       114  Department of the Interior (Parts 114-1--114-99)
       115  Environmental Protection Agency (Parts 115-1--115-99)
       128  Department of Justice (Parts 128-1--128-99)
  129--200  [Reserved]
            Subtitle D--Federal Acquisition Supply Chain Security
       201  Federal Acquisition Security Council (Parts 201-1--
                201-99).
            Subtitle E [Reserved]
            Subtitle F--Federal Travel Regulation System
       300  General (Parts 300-1--300-99)
       301  Temporary Duty (TDY) Travel Allowances (Parts 301-1--
                301-99)
       302  Relocation Allowances (Parts 302-1--302-99)
       303  Payment of Expenses Connected with the Death of 
                Certain Employees (Part 303-1--303-99)
       304  Payment of Travel Expenses from a Non-Federal Source 
                (Parts 304-1--304-99)

                        Title 42--Public Health

         I  Public Health Service, Department of Health and Human 
                Services (Parts 1--199)
   II--III  [Reserved]
        IV  Centers for Medicare & Medicaid Services, Department 
                of Health and Human Services (Parts 400--699)
         V  Office of Inspector General-Health Care, Department of 
                Health and Human Services (Parts 1000--1099)

                   Title 43--Public Lands: Interior

            Subtitle A--Office of the Secretary of the Interior 
                (Parts 1--199)
            Subtitle B--Regulations Relating to Public Lands
         I  Bureau of Reclamation, Department of the Interior 
                (Parts 400--999)
        II  Bureau of Land Management, Department of the Interior 
                (Parts 1000--9999)
       III  Utah Reclamation Mitigation and Conservation 
                Commission (Parts 10000--10099)

             Title 44--Emergency Management and Assistance

         I  Federal Emergency Management Agency, Department of 
                Homeland Security (Parts 0--399)
        IV  Department of Commerce and Department of 
                Transportation (Parts 400--499)

[[Page 801]]

                       Title 45--Public Welfare

            Subtitle A--Department of Health and Human Services 
                (Parts 1--199)
            Subtitle B--Regulations Relating to Public Welfare
        II  Office of Family Assistance (Assistance Programs), 
                Administration for Children and Families, 
                Department of Health and Human Services (Parts 
                200--299)
       III  Office of Child Support Enforcement (Child Support 
                Enforcement Program), Administration for Children 
                and Families, Department of Health and Human 
                Services (Parts 300--399)
        IV  Office of Refugee Resettlement, Administration for 
                Children and Families, Department of Health and 
                Human Services (Parts 400--499)
         V  Foreign Claims Settlement Commission of the United 
                States, Department of Justice (Parts 500--599)
        VI  National Science Foundation (Parts 600--699)
       VII  Commission on Civil Rights (Parts 700--799)
      VIII  Office of Personnel Management (Parts 800--899)
        IX  Denali Commission (Parts 900--999)
         X  Office of Community Services, Administration for 
                Children and Families, Department of Health and 
                Human Services (Parts 1000--1099)
        XI  National Foundation on the Arts and the Humanities 
                (Parts 1100--1199)
       XII  Corporation for National and Community Service (Parts 
                1200--1299)
      XIII  Administration for Children and Families, Department 
                of Health and Human Services (Parts 1300--1399)
       XVI  Legal Services Corporation (Parts 1600--1699)
      XVII  National Commission on Libraries and Information 
                Science (Parts 1700--1799)
     XVIII  Harry S. Truman Scholarship Foundation (Parts 1800--
                1899)
       XXI  Commission of Fine Arts (Parts 2100--2199)
     XXIII  Arctic Research Commission (Parts 2300--2399)
      XXIV  James Madison Memorial Fellowship Foundation (Parts 
                2400--2499)
       XXV  Corporation for National and Community Service (Parts 
                2500--2599)

                          Title 46--Shipping

         I  Coast Guard, Department of Homeland Security (Parts 
                1--199)
        II  Maritime Administration, Department of Transportation 
                (Parts 200--399)
       III  Coast Guard (Great Lakes Pilotage), Department of 
                Homeland Security (Parts 400--499)
        IV  Federal Maritime Commission (Parts 500--599)

[[Page 802]]

                      Title 47--Telecommunication

         I  Federal Communications Commission (Parts 0--199)
        II  Office of Science and Technology Policy and National 
                Security Council (Parts 200--299)
       III  National Telecommunications and Information 
                Administration, Department of Commerce (Parts 
                300--399)
        IV  National Telecommunications and Information 
                Administration, Department of Commerce, and 
                National Highway Traffic Safety Administration, 
                Department of Transportation (Parts 400--499)
         V  The First Responder Network Authority (Parts 500--599)

           Title 48--Federal Acquisition Regulations System

         1  Federal Acquisition Regulation (Parts 1--99)
         2  Defense Acquisition Regulations System, Department of 
                Defense (Parts 200--299)
         3  Department of Health and Human Services (Parts 300--
                399)
         4  Department of Agriculture (Parts 400--499)
         5  General Services Administration (Parts 500--599)
         6  Department of State (Parts 600--699)
         7  Agency for International Development (Parts 700--799)
         8  Department of Veterans Affairs (Parts 800--899)
         9  Department of Energy (Parts 900--999)
        10  Department of the Treasury (Parts 1000--1099)
        12  Department of Transportation (Parts 1200--1299)
        13  Department of Commerce (Parts 1300--1399)
        14  Department of the Interior (Parts 1400--1499)
        15  Environmental Protection Agency (Parts 1500--1599)
        16  Office of Personnel Management, Federal Employees 
                Health Benefits Acquisition Regulation (Parts 
                1600--1699)
        17  Office of Personnel Management (Parts 1700--1799)
        18  National Aeronautics and Space Administration (Parts 
                1800--1899)
        19  Broadcasting Board of Governors (Parts 1900--1999)
        20  Nuclear Regulatory Commission (Parts 2000--2099)
        21  Office of Personnel Management, Federal Employees 
                Group Life Insurance Federal Acquisition 
                Regulation (Parts 2100--2199)
        23  Social Security Administration (Parts 2300--2399)
        24  Department of Housing and Urban Development (Parts 
                2400--2499)
        25  National Science Foundation (Parts 2500--2599)
        28  Department of Justice (Parts 2800--2899)
        29  Department of Labor (Parts 2900--2999)
        30  Department of Homeland Security, Homeland Security 
                Acquisition Regulation (HSAR) (Parts 3000--3099)
        34  Department of Education Acquisition Regulation (Parts 
                3400--3499)

[[Page 803]]

        51  Department of the Army Acquisition Regulations (Parts 
                5100--5199) [Reserved]
        52  Department of the Navy Acquisition Regulations (Parts 
                5200--5299)
        53  Department of the Air Force Federal Acquisition 
                Regulation Supplement (Parts 5300--5399) 
                [Reserved]
        54  Defense Logistics Agency, Department of Defense (Parts 
                5400--5499)
        57  African Development Foundation (Parts 5700--5799)
        61  Civilian Board of Contract Appeals, General Services 
                Administration (Parts 6100--6199)
        99  Cost Accounting Standards Board, Office of Federal 
                Procurement Policy, Office of Management and 
                Budget (Parts 9900--9999)

                       Title 49--Transportation

            Subtitle A--Office of the Secretary of Transportation 
                (Parts 1--99)
            Subtitle B--Other Regulations Relating to 
                Transportation
         I  Pipeline and Hazardous Materials Safety 
                Administration, Department of Transportation 
                (Parts 100--199)
        II  Federal Railroad Administration, Department of 
                Transportation (Parts 200--299)
       III  Federal Motor Carrier Safety Administration, 
                Department of Transportation (Parts 300--399)
        IV  Coast Guard, Department of Homeland Security (Parts 
                400--499)
         V  National Highway Traffic Safety Administration, 
                Department of Transportation (Parts 500--599)
        VI  Federal Transit Administration, Department of 
                Transportation (Parts 600--699)
       VII  National Railroad Passenger Corporation (AMTRAK) 
                (Parts 700--799)
      VIII  National Transportation Safety Board (Parts 800--999)
         X  Surface Transportation Board (Parts 1000--1399)
        XI  Research and Innovative Technology Administration, 
                Department of Transportation (Parts 1400--1499) 
                [Reserved]
       XII  Transportation Security Administration, Department of 
                Homeland Security (Parts 1500--1699)

                   Title 50--Wildlife and Fisheries

         I  United States Fish and Wildlife Service, Department of 
                the Interior (Parts 1--199)
        II  National Marine Fisheries Service, National Oceanic 
                and Atmospheric Administration, Department of 
                Commerce (Parts 200--299)
       III  International Fishing and Related Activities (Parts 
                300--399)

[[Page 804]]

        IV  Joint Regulations (United States Fish and Wildlife 
                Service, Department of the Interior and National 
                Marine Fisheries Service, National Oceanic and 
                Atmospheric Administration, Department of 
                Commerce); Endangered Species Committee 
                Regulations (Parts 400--499)
         V  Marine Mammal Commission (Parts 500--599)
        VI  Fishery Conservation and Management, National Oceanic 
                and Atmospheric Administration, Department of 
                Commerce (Parts 600--699)

[[Page 805]]





           Alphabetical List of Agencies Appearing in the CFR




                      (Revised as of July 1, 2023)

                                                  CFR Title, Subtitle or 
                     Agency                               Chapter

Administrative Conference of the United States    1, III
Advisory Council on Historic Preservation         36, VIII
Advocacy and Outreach, Office of                  7, XXV
Afghanistan Reconstruction, Special Inspector     5, LXXXIII
     General for
African Development Foundation                    22, XV
  Federal Acquisition Regulation                  48, 57
Agency for International Development              2, VII; 22, II
  Federal Acquisition Regulation                  48, 7
Agricultural Marketing Service                    7, I, VIII, IX, X, XI; 9, 
                                                  II
Agricultural Research Service                     7, V
Agriculture, Department of                        2, IV; 5, LXXIII
  Advocacy and Outreach, Office of                7, XXV
  Agricultural Marketing Service                  7, I, VIII, IX, X, XI; 9, 
                                                  II
  Agricultural Research Service                   7, V
  Animal and Plant Health Inspection Service      7, III; 9, I
  Chief Financial Officer, Office of              7, XXX
  Commodity Credit Corporation                    7, XIV
  Economic Research Service                       7, XXXVII
  Energy Policy and New Uses, Office of           2, IX; 7, XXIX
  Environmental Quality, Office of                7, XXXI
  Farm Service Agency                             7, VII, XVIII
  Federal Acquisition Regulation                  48, 4
  Federal Crop Insurance Corporation              7, IV
  Food and Nutrition Service                      7, II
  Food Safety and Inspection Service              9, III
  Foreign Agricultural Service                    7, XV
  Forest Service                                  36, II
  Information Resources Management, Office of     7, XXVII
  Inspector General, Office of                    7, XXVI
  National Agricultural Library                   7, XLI
  National Agricultural Statistics Service        7, XXXVI
  National Institute of Food and Agriculture      7, XXXIV
  Natural Resources Conservation Service          7, VI
  Operations, Office of                           7, XXVIII
  Procurement and Property Management, Office of  7, XXXII
  Rural Business-Cooperative Service              7, XVIII, XLII
  Rural Development Administration                7, XLII
  Rural Housing Service                           7, XVIII, XXXV
  Rural Utilities Service                         7, XVII, XVIII, XLII
  Secretary of Agriculture, Office of             7, Subtitle A
  Transportation, Office of                       7, XXXIII
  World Agricultural Outlook Board                7, XXXVIII
Air Force, Department of                          32, VII
  Federal Acquisition Regulation Supplement       48, 53
Air Transportation Stabilization Board            14, VI
Alcohol and Tobacco Tax and Trade Bureau          27, I
Alcohol, Tobacco, Firearms, and Explosives,       27, II
     Bureau of
AMTRAK                                            49, VII
American Battle Monuments Commission              36, IV
American Indians, Office of the Special Trustee   25, VII
Animal and Plant Health Inspection Service        7, III; 9, I
Appalachian Regional Commission                   5, IX
Architectural and Transportation Barriers         36, XI
   Compliance Board
[[Page 806]]

Arctic Research Commission                        45, XXIII
Armed Forces Retirement Home                      5, XI; 38, II
Army, Department of                               32, V
  Engineers, Corps of                             33, II; 36, III
  Federal Acquisition Regulation                  48, 51
Benefits Review Board                             20, VII
Bilingual Education and Minority Languages        34, V
     Affairs, Office of
Blind or Severely Disabled, Committee for         41, 51
     Purchase from People Who Are
  Federal Acquisition Regulation                  48, 19
Career, Technical, and Adult Education, Office    34, IV
     of
Census Bureau                                     15, I
Centers for Medicare & Medicaid Services          42, IV
Central Intelligence Agency                       32, XIX
Chemical Safety and Hazard Investigation Board    40, VI
Chief Financial Officer, Office of                7, XXX
Child Support Enforcement, Office of              45, III
Children and Families, Administration for         45, II, III, IV, X, XIII
Civil Rights, Commission on                       5, LXVIII; 45, VII
Civil Rights, Office for                          34, I
Coast Guard                                       33, I; 46, I; 49, IV
Coast Guard (Great Lakes Pilotage)                46, III
Commerce, Department of                           2, XIII; 44, IV; 50, VI
  Census Bureau                                   15, I
  Economic Affairs, Office of the Under-          15, XV
       Secretary for
  Economic Analysis, Bureau of                    15, VIII
  Economic Development Administration             13, III
  Emergency Management and Assistance             44, IV
  Federal Acquisition Regulation                  48, 13
  Foreign-Trade Zones Board                       15, IV
  Industry and Security, Bureau of                15, VII
  International Trade Administration              15, III; 19, III
  National Institute of Standards and Technology  15, II; 37, IV
  National Marine Fisheries Service               50, II, IV
  National Oceanic and Atmospheric                15, IX; 50, II, III, IV, 
       Administration                             VI
  National Technical Information Service          15, XI
  National Telecommunications and Information     15, XXIII; 47, III, IV
       Administration
  National Weather Service                        15, IX
  Patent and Trademark Office, United States      37, I
  Secretary of Commerce, Office of                15, Subtitle A
Commercial Space Transportation                   14, III
Commodity Credit Corporation                      7, XIV
Commodity Futures Trading Commission              5, XLI; 17, I
Community Planning and Development, Office of     24, V, VI
     Assistant Secretary for
Community Services, Office of                     45, X
Comptroller of the Currency                       12, I
Construction Industry Collective Bargaining       29, IX
     Commission
Consumer Financial Protection Bureau              5, LXXXIV; 12, X
Consumer Product Safety Commission                5, LXXI; 16, II
Copyright Royalty Board                           37, III
Corporation for National and Community Service    2, XXII; 45, XII, XXV
Cost Accounting Standards Board                   48, 99
Council on Environmental Quality                  40, V
Council of the Inspectors General on Integrity    5, XCVIII
     and Efficiency
Court Services and Offender Supervision Agency    5, LXX; 28, VIII
     for the District of Columbia
Customs and Border Protection                     19, I
Defense, Department of                            2, XI; 5, XXVI; 32, 
                                                  Subtitle A; 40, VII
  Advanced Research Projects Agency               32, I
  Air Force Department                            32, VII
  Army Department                                 32, V; 33, II; 36, III; 
                                                  48, 51
  Defense Acquisition Regulations System          48, 2
  Defense Intelligence Agency                     32, I

[[Page 807]]

  Defense Logistics Agency                        32, I, XII; 48, 54
  Engineers, Corps of                             33, II; 36, III
  National Imagery and Mapping Agency             32, I
  Navy, Department of                             32, VI; 48, 52
  Secretary of Defense, Office of                 2, XI; 32, I
Defense Contract Audit Agency                     32, I
Defense Intelligence Agency                       32, I
Defense Logistics Agency                          32, XII; 48, 54
Defense Nuclear Facilities Safety Board           10, XVII
Delaware River Basin Commission                   18, III
Denali Commission                                 45, IX
Disability, National Council on                   5, C; 34, XII
District of Columbia, Court Services and          5, LXX; 28, VIII
     Offender Supervision Agency for the
Drug Enforcement Administration                   21, II
East-West Foreign Trade Board                     15, XIII
Economic Affairs, Office of the Under-Secretary   15, XV
     for
Economic Analysis, Bureau of                      15, VIII
Economic Development Administration               13, III
Economic Research Service                         7, XXXVII
Education, Department of                          2, XXXIV; 5, LIII
  Bilingual Education and Minority Languages      34, V
       Affairs, Office of
  Career, Technical, and Adult Education, Office  34, IV
       of
  Civil Rights, Office for                        34, I
  Educational Research and Improvement, Office    34, VII
       of
  Elementary and Secondary Education, Office of   34, II
  Federal Acquisition Regulation                  48, 34
  Postsecondary Education, Office of              34, VI
  Secretary of Education, Office of               34, Subtitle A
  Special Education and Rehabilitative Services,  34, III
       Office of
Educational Research and Improvement, Office of   34, VII
Election Assistance Commission                    2, LVIII; 11, II
Elementary and Secondary Education, Office of     34, II
Emergency Oil and Gas Guaranteed Loan Board       13, V
Emergency Steel Guarantee Loan Board              13, IV
Employee Benefits Security Administration         29, XXV
Employees' Compensation Appeals Board             20, IV
Employees Loyalty Board                           5, V
Employment and Training Administration            20, V
Employment Policy, National Commission for        1, IV
Employment Standards Administration               20, VI
Endangered Species Committee                      50, IV
Energy, Department of                             2, IX; 5, XXIII; 10, II, 
                                                  III, X
  Federal Acquisition Regulation                  48, 9
  Federal Energy Regulatory Commission            5, XXIV; 18, I
  Property Management Regulations                 41, 109
Energy, Office of                                 7, XXIX
Engineers, Corps of                               33, II; 36, III
Engraving and Printing, Bureau of                 31, VI
Environmental Protection Agency                   2, XV; 5, LIV; 40, I, IV, 
                                                  VII
  Federal Acquisition Regulation                  48, 15
  Property Management Regulations                 41, 115
Environmental Quality, Office of                  7, XXXI
Equal Employment Opportunity Commission           5, LXII; 29, XIV
Equal Opportunity, Office of Assistant Secretary  24, I
     for
Executive Office of the President                 3, I
  Environmental Quality, Council on               40, V
  Management and Budget, Office of                2, Subtitle A; 5, III, 
                                                  LXXVII; 14, VI; 48, 99
  National Drug Control Policy, Office of         2, XXXVI; 21, III
  National Security Council                       32, XXI; 47, II
  Presidential Documents                          3
  Science and Technology Policy, Office of        32, XXIV; 47, II
  Trade Representative, Office of the United      15, XX
     States
[[Page 808]]

Export-Import Bank of the United States           2, XXXV; 5, LII; 12, IV
Family Assistance, Office of                      45, II
Farm Credit Administration                        5, XXXI; 12, VI
Farm Credit System Insurance Corporation          5, XXX; 12, XIV
Farm Service Agency                               7, VII, XVIII
Federal Acquisition Regulation                    48, 1
Federal Acquisition Security Council              41, 201
Federal Aviation Administration                   14, I
  Commercial Space Transportation                 14, III
Federal Claims Collection Standards               31, IX
Federal Communications Commission                 2, LX; 5, XXIX; 47, I
Federal Contract Compliance Programs, Office of   41, 60
Federal Crop Insurance Corporation                7, IV
Federal Deposit Insurance Corporation             5, XXII; 12, III
Federal Election Commission                       5, XXXVII; 11, I
Federal Emergency Management Agency               44, I
Federal Employees Group Life Insurance Federal    48, 21
     Acquisition Regulation
Federal Employees Health Benefits Acquisition     48, 16
     Regulation
Federal Energy Regulatory Commission              5, XXIV; 18, I
Federal Financial Institutions Examination        12, XI
     Council
Federal Financing Bank                            12, VIII
Federal Highway Administration                    23, I, II
Federal Home Loan Mortgage Corporation            1, IV
Federal Housing Enterprise Oversight Office       12, XVII
Federal Housing Finance Agency                    5, LXXX; 12, XII
Federal Labor Relations Authority                 5, XIV, XLIX; 22, XIV
Federal Law Enforcement Training Center           31, VII
Federal Management Regulation                     41, 102
Federal Maritime Commission                       46, IV
Federal Mediation and Conciliation Service        29, XII
Federal Mine Safety and Health Review Commission  5, LXXIV; 29, XXVII
Federal Motor Carrier Safety Administration       49, III
Federal Permitting Improvement Steering Council   40, IX
Federal Prison Industries, Inc.                   28, III
Federal Procurement Policy Office                 48, 99
Federal Property Management Regulations           41, 101
Federal Railroad Administration                   49, II
Federal Register, Administrative Committee of     1, I
Federal Register, Office of                       1, II
Federal Reserve System                            12, II
  Board of Governors                              5, LVIII
Federal Retirement Thrift Investment Board        5, VI, LXXVI
Federal Service Impasses Panel                    5, XIV
Federal Trade Commission                          5, XLVII; 16, I
Federal Transit Administration                    49, VI
Federal Travel Regulation System                  41, Subtitle F
Financial Crimes Enforcement Network              31, X
Financial Research Office                         12, XVI
Financial Stability Oversight Council             12, XIII
Fine Arts, Commission of                          45, XXI
Fiscal Service                                    31, II
Fish and Wildlife Service, United States          50, I, IV
Food and Drug Administration                      21, I
Food and Nutrition Service                        7, II
Food Safety and Inspection Service                9, III
Foreign Agricultural Service                      7, XV
Foreign Assets Control, Office of                 31, V
Foreign Claims Settlement Commission of the       45, V
     United States
Foreign Service Grievance Board                   22, IX
Foreign Service Impasse Disputes Panel            22, XIV
Foreign Service Labor Relations Board             22, XIV
Foreign-Trade Zones Board                         15, IV
Forest Service                                    36, II
General Services Administration                   5, LVII; 41, 105
  Contract Appeals, Board of                      48, 61
  Federal Acquisition Regulation                  48, 5

[[Page 809]]

  Federal Management Regulation                   41, 102
  Federal Property Management Regulations         41, 101
  Federal Travel Regulation System                41, Subtitle F
  General                                         41, 300
  Payment From a Non-Federal Source for Travel    41, 304
       Expenses
  Payment of Expenses Connected With the Death    41, 303
       of Certain Employees
  Relocation Allowances                           41, 302
  Temporary Duty (TDY) Travel Allowances          41, 301
Geological Survey                                 30, IV
Government Accountability Office                  4, I
Government Ethics, Office of                      5, XVI
Government National Mortgage Association          24, III
Grain Inspection, Packers and Stockyards          7, VIII; 9, II
     Administration
Great Lakes St. Lawrence Seaway Development       33, IV
     Corporation
Gulf Coast Ecosystem Restoration Council          2, LIX; 40, VIII
Harry S. Truman Scholarship Foundation            45, XVIII
Health and Human Services, Department of          2, III; 5, XLV; 45, 
                                                  Subtitle A
  Centers for Medicare & Medicaid Services        42, IV
  Child Support Enforcement, Office of            45, III
  Children and Families, Administration for       45, II, III, IV, X, XIII
  Community Services, Office of                   45, X
  Family Assistance, Office of                    45, II
  Federal Acquisition Regulation                  48, 3
  Food and Drug Administration                    21, I
  Indian Health Service                           25, V
  Inspector General (Health Care), Office of      42, V
  Public Health Service                           42, I
  Refugee Resettlement, Office of                 45, IV
Homeland Security, Department of                  2, XXX; 5, XXXVI; 6, I; 8, 
                                                  I
  Coast Guard                                     33, I; 46, I; 49, IV
  Coast Guard (Great Lakes Pilotage)              46, III
  Customs and Border Protection                   19, I
  Federal Emergency Management Agency             44, I
  Human Resources Management and Labor Relations  5, XCVII
       Systems
  Immigration and Customs Enforcement Bureau      19, IV
  Transportation Security Administration          49, XII
HOPE for Homeowners Program, Board of Directors   24, XXIV
     of
Housing and Urban Development, Department of      2, XXIV; 5, LXV; 24, 
                                                  Subtitle B
  Community Planning and Development, Office of   24, V, VI
       Assistant Secretary for
  Equal Opportunity, Office of Assistant          24, I
       Secretary for
  Federal Acquisition Regulation                  48, 24
  Federal Housing Enterprise Oversight, Office    12, XVII
       of
  Government National Mortgage Association        24, III
  Housing--Federal Housing Commissioner, Office   24, II, VIII, X, XX
       of Assistant Secretary for
  Housing, Office of, and Multifamily Housing     24, IV
       Assistance Restructuring, Office of
  Inspector General, Office of                    24, XII
  Public and Indian Housing, Office of Assistant  24, IX
       Secretary for
  Secretary, Office of                            24, Subtitle A, VII
Housing--Federal Housing Commissioner, Office of  24, II, VIII, X, XX
     Assistant Secretary for
Housing, Office of, and Multifamily Housing       24, IV
     Assistance Restructuring, Office of
Immigration and Customs Enforcement Bureau        19, IV
Immigration Review, Executive Office for          8, V
Independent Counsel, Office of                    28, VII
Independent Counsel, Offices of                   28, VI
Indian Affairs, Bureau of                         25, I, V
Indian Affairs, Office of the Assistant           25, VI
     Secretary
Indian Arts and Crafts Board                      25, II

[[Page 810]]

Indian Health Service                             25, V
Industry and Security, Bureau of                  15, VII
Information Resources Management, Office of       7, XXVII
Information Security Oversight Office, National   32, XX
     Archives and Records Administration
Inspector General
  Agriculture Department                          7, XXVI
  Health and Human Services Department            42, V
  Housing and Urban Development Department        24, XII, XV
Institute of Peace, United States                 22, XVII
Intellectual Property Enforcement Coordinator,    5, CIV
     Office of
Inter-American Foundation                         5, LXIII; 22, X
Interior, Department of                           2, XIV
  American Indians, Office of the Special         25, VII
       Trustee
  Endangered Species Committee                    50, IV
  Federal Acquisition Regulation                  48, 14
  Federal Property Management Regulations System  41, 114
  Fish and Wildlife Service, United States        50, I, IV
  Geological Survey                               30, IV
  Indian Affairs, Bureau of                       25, I, V
  Indian Affairs, Office of the Assistant         25, VI
       Secretary
  Indian Arts and Crafts Board                    25, II
  Land Management, Bureau of                      43, II
  National Indian Gaming Commission               25, III
  National Park Service                           36, I
  Natural Resource Revenue, Office of             30, XII
  Ocean Energy Management, Bureau of              30, V
  Reclamation, Bureau of                          43, I
  Safety and Environmental Enforcement, Bureau    30, II
       of
  Secretary of the Interior, Office of            2, XIV; 43, Subtitle A
  Surface Mining Reclamation and Enforcement,     30, VII
       Office of
Internal Revenue Service                          26, I
International Boundary and Water Commission,      22, XI
     United States and Mexico, United States 
     Section
International Development, United States Agency   22, II
     for
  Federal Acquisition Regulation                  48, 7
International Development Cooperation Agency,     22, XII
     United States
International Development Finance Corporation,    5, XXXIII; 22, VII
     U.S.
International Joint Commission, United States     22, IV
     and Canada
International Organizations Employees Loyalty     5, V
     Board
International Trade Administration                15, III; 19, III
International Trade Commission, United States     19, II
Interstate Commerce Commission                    5, XL
Investment Security, Office of                    31, VIII
James Madison Memorial Fellowship Foundation      45, XXIV
Japan-United States Friendship Commission         22, XVI
Joint Board for the Enrollment of Actuaries       20, VIII
Justice, Department of                            2, XXVIII; 5, XXVIII; 28, 
                                                  I, XI; 40, IV
  Alcohol, Tobacco, Firearms, and Explosives,     27, II
       Bureau of
  Drug Enforcement Administration                 21, II
  Federal Acquisition Regulation                  48, 28
  Federal Claims Collection Standards             31, IX
  Federal Prison Industries, Inc.                 28, III
  Foreign Claims Settlement Commission of the     45, V
       United States
  Immigration Review, Executive Office for        8, V
  Independent Counsel, Offices of                 28, VI
  Prisons, Bureau of                              28, V
  Property Management Regulations                 41, 128
Labor, Department of                              2, XXIX; 5, XLII
  Benefits Review Board                           20, VII
  Employee Benefits Security Administration       29, XXV
  Employees' Compensation Appeals Board           20, IV
  Employment and Training Administration          20, V
  Federal Acquisition Regulation                  48, 29

[[Page 811]]

  Federal Contract Compliance Programs, Office    41, 60
       of
  Federal Procurement Regulations System          41, 50
  Labor-Management Standards, Office of           29, II, IV
  Mine Safety and Health Administration           30, I
  Occupational Safety and Health Administration   29, XVII
  Public Contracts                                41, 50
  Secretary of Labor, Office of                   29, Subtitle A
  Veterans' Employment and Training Service,      41, 61; 20, IX
       Office of the Assistant Secretary for
  Wage and Hour Division                          29, V
  Workers' Compensation Programs, Office of       20, I, VI
Labor-Management Standards, Office of             29, II, IV
Land Management, Bureau of                        43, II
Legal Services Corporation                        45, XVI
Libraries and Information Science, National       45, XVII
     Commission on
Library of Congress                               36, VII
  Copyright Royalty Board                         37, III
  U.S. Copyright Office                           37, II
Management and Budget, Office of                  5, III, LXXVII; 14, VI; 
                                                  48, 99
Marine Mammal Commission                          50, V
Maritime Administration                           46, II
Merit Systems Protection Board                    5, II, LXIV
Micronesian Status Negotiations, Office for       32, XXVII
Military Compensation and Retirement              5, XCIX
     Modernization Commission
Millennium Challenge Corporation                  22, XIII
Mine Safety and Health Administration             30, I
Minority Business Development Agency              15, XIV
Miscellaneous Agencies                            1, IV
Monetary Offices                                  31, I
Morris K. Udall Scholarship and Excellence in     36, XVI
     National Environmental Policy Foundation
Museum and Library Services, Institute of         2, XXXI
National Aeronautics and Space Administration     2, XVIII; 5, LIX; 14, V
  Federal Acquisition Regulation                  48, 18
National Agricultural Library                     7, XLI
National Agricultural Statistics Service          7, XXXVI
National and Community Service, Corporation for   2, XXII; 45, XII, XXV
National Archives and Records Administration      2, XXVI; 5, LXVI; 36, XII
  Information Security Oversight Office           32, XX
National Capital Planning Commission              1, IV, VI
National Counterintelligence Center               32, XVIII
National Credit Union Administration              5, LXXXVI; 12, VII
National Crime Prevention and Privacy Compact     28, IX
     Council
National Drug Control Policy, Office of           2, XXXVI; 21, III
National Endowment for the Arts                   2, XXXII
National Endowment for the Humanities             2, XXXIII
National Foundation on the Arts and the           45, XI
     Humanities
National Geospatial-Intelligence Agency           32, I
National Highway Traffic Safety Administration    23, II, III; 47, VI; 49, V
National Imagery and Mapping Agency               32, I
National Indian Gaming Commission                 25, III
National Institute of Food and Agriculture        7, XXXIV
National Institute of Standards and Technology    15, II; 37, IV
National Intelligence, Office of Director of      5, IV; 32, XVII
National Labor Relations Board                    5, LXI; 29, I
National Marine Fisheries Service                 50, II, IV
National Mediation Board                          5, CI; 29, X
National Oceanic and Atmospheric Administration   15, IX; 50, II, III, IV, 
                                                  VI
National Park Service                             36, I
National Railroad Adjustment Board                29, III
National Railroad Passenger Corporation (AMTRAK)  49, VII
National Science Foundation                       2, XXV; 5, XLIII; 45, VI
  Federal Acquisition Regulation                  48, 25
National Security Council                         32, XXI; 47, II

[[Page 812]]

National Technical Information Service            15, XI
National Telecommunications and Information       15, XXIII; 47, III, IV, V
     Administration
National Transportation Safety Board              49, VIII
Natural Resource Revenue, Office of               30, XII
Natural Resources Conservation Service            7, VI
Navajo and Hopi Indian Relocation, Office of      25, IV
Navy, Department of                               32, VI
  Federal Acquisition Regulation                  48, 52
Neighborhood Reinvestment Corporation             24, XXV
Northeast Interstate Low-Level Radioactive Waste  10, XVIII
     Commission
Nuclear Regulatory Commission                     2, XX; 5, XLVIII; 10, I
  Federal Acquisition Regulation                  48, 20
Occupational Safety and Health Administration     29, XVII
Occupational Safety and Health Review Commission  29, XX
Ocean Energy Management, Bureau of                30, V
Oklahoma City National Memorial Trust             36, XV
Operations Office                                 7, XXVIII
Patent and Trademark Office, United States        37, I
Payment From a Non-Federal Source for Travel      41, 304
     Expenses
Payment of Expenses Connected With the Death of   41, 303
     Certain Employees
Peace Corps                                       2, XXXVII; 22, III
Pennsylvania Avenue Development Corporation       36, IX
Pension Benefit Guaranty Corporation              29, XL
Personnel Management, Office of                   5, I, IV, XXXV; 45, VIII
  Federal Acquisition Regulation                  48, 17
  Federal Employees Group Life Insurance Federal  48, 21
       Acquisition Regulation
  Federal Employees Health Benefits Acquisition   48, 16
       Regulation
  Human Resources Management and Labor Relations  5, XCVII
       Systems, Department of Homeland Security
Pipeline and Hazardous Materials Safety           49, I
     Administration
Postal Regulatory Commission                      5, XLVI; 39, III
Postal Service, United States                     5, LX; 39, I
Postsecondary Education, Office of                34, VI
President's Commission on White House             1, IV
     Fellowships
Presidential Documents                            3
Presidio Trust                                    36, X
Prisons, Bureau of                                28, V
Privacy and Civil Liberties Oversight Board       6, X
Procurement and Property Management, Office of    7, XXXII
Public and Indian Housing, Office of Assistant    24, IX
     Secretary for
Public Contracts, Department of Labor             41, 50
Public Health Service                             42, I
Railroad Retirement Board                         20, II
Reclamation, Bureau of                            43, I
Refugee Resettlement, Office of                   45, IV
Relocation Allowances                             41, 302
Research and Innovative Technology                49, XI
     Administration
Rural Business-Cooperative Service                7, XVIII, XLII, L
Rural Development Administration                  7, XLII
Rural Housing Service                             7, XVIII, XXXV, L
Rural Utilities Service                           7, XVII, XVIII, XLII, L
Safety and Environmental Enforcement, Bureau of   30, II
Science and Technology Policy, Office of          32, XXIV; 47, II
Secret Service                                    31, IV
Securities and Exchange Commission                5, XXXIV; 17, II
Selective Service System                          32, XVI
Small Business Administration                     2, XXVII; 13, I
Smithsonian Institution                           36, V
Social Security Administration                    2, XXIII; 20, III; 48, 23
Soldiers' and Airmen's Home, United States        5, XI
Special Counsel, Office of                        5, VIII
Special Education and Rehabilitative Services,    34, III
     Office of
State, Department of                              2, VI; 22, I; 28, XI

[[Page 813]]

  Federal Acquisition Regulation                  48, 6
Surface Mining Reclamation and Enforcement,       30, VII
     Office of
Surface Transportation Board                      49, X
Susquehanna River Basin Commission                18, VIII
Tennessee Valley Authority                        5, LXIX; 18, XIII
Trade Representative, United States, Office of    15, XX
Transportation, Department of                     2, XII; 5, L
  Commercial Space Transportation                 14, III
  Emergency Management and Assistance             44, IV
  Federal Acquisition Regulation                  48, 12
  Federal Aviation Administration                 14, I
  Federal Highway Administration                  23, I, II
  Federal Motor Carrier Safety Administration     49, III
  Federal Railroad Administration                 49, II
  Federal Transit Administration                  49, VI
  Great Lakes St. Lawrence Seaway Development     33, IV
       Corporation
  Maritime Administration                         46, II
  National Highway Traffic Safety Administration  23, II, III; 47, IV; 49, V
  Pipeline and Hazardous Materials Safety         49, I
       Administration
  Secretary of Transportation, Office of          14, II; 49, Subtitle A
  Transportation Statistics Bureau                49, XI
Transportation, Office of                         7, XXXIII
Transportation Security Administration            49, XII
Transportation Statistics Bureau                  49, XI
Travel Allowances, Temporary Duty (TDY)           41, 301
Treasury, Department of the                       2, X; 5, XXI; 12, XV; 17, 
                                                  IV; 31, IX
  Alcohol and Tobacco Tax and Trade Bureau        27, I
  Community Development Financial Institutions    12, XVIII
       Fund
  Comptroller of the Currency                     12, I
  Customs and Border Protection                   19, I
  Engraving and Printing, Bureau of               31, VI
  Federal Acquisition Regulation                  48, 10
  Federal Claims Collection Standards             31, IX
  Federal Law Enforcement Training Center         31, VII
  Financial Crimes Enforcement Network            31, X
  Fiscal Service                                  31, II
  Foreign Assets Control, Office of               31, V
  Internal Revenue Service                        26, I
  Investment Security, Office of                  31, VIII
  Monetary Offices                                31, I
  Secret Service                                  31, IV
  Secretary of the Treasury, Office of            31, Subtitle A
Truman, Harry S. Scholarship Foundation           45, XVIII
United States Agency for Global Media             22, V
United States and Canada, International Joint     22, IV
     Commission
United States and Mexico, International Boundary  22, XI
     and Water Commission, United States Section
U.S. Copyright Office                             37, II
U.S. Office of Special Counsel                    5, CII
Utah Reclamation Mitigation and Conservation      43, III
     Commission
Veterans Affairs, Department of                   2, VIII; 38, I
  Federal Acquisition Regulation                  48, 8
Veterans' Employment and Training Service,        41, 61; 20, IX
     Office of the Assistant Secretary for
Vice President of the United States, Office of    32, XXVIII
Wage and Hour Division                            29, V
Water Resources Council                           18, VI
Workers' Compensation Programs, Office of         20, I, VII
World Agricultural Outlook Board                  7, XXXVIII

[[Page 815]]



List of CFR Sections Affected



All changes in this volume of the Code of Federal Regulations (CFR) that 
were made by documents published in the Federal Register since January 
1, 2018 are enumerated in the following list. Entries indicate the 
nature of the changes effected. Page numbers refer to Federal Register 
pages. The user should consult the entries for chapters, parts and 
subparts as well as sections for revisions.
For changes to this volume of the CFR prior to this listing, consult the 
annual edition of the monthly List of CFR Sections Affected (LSA). The 
LSA is available at www.govinfo.gov. For changes to this volume of the 
CFR prior to 2001, see the ``List of CFR Sections Affected, 1949-1963, 
1964-1972, 1973-1985, and 1986-2000'' published in 11 separate volumes. 
The ``List of CFR Sections Affected 1986-2000'' is available at 
www.govinfo.gov.

                                  2018

40 CFR
                                                                   83 FR
                                                                    Page
Chapter I
790.45 (c)(7) and (g) added........................................52723
790.59 (c) added...................................................52723
790.60 (a)(18) and (d) added.......................................52724
790.65 (b) revised.................................................52724
791.39 (a)(3) removed; (b) revised.................................52724

                                  2019

40 CFR
                                                                   84 FR
                                                                    Page
Chapter I
1065.670 (a) introductory text reinstated; CFR correction...........9243

                                  2020

40 CFR
                                                                   85 FR
                                                                    Page
Chapter I
1065.701 (d)(2) revised............................................78468
1065.703 Table 1 revised...........................................78468
1065.705 Introductory text amended.................................78468
1065.725 (c) amended...............................................78468
1065.1010 (a) amended; (b)(19), (35), and (46) revised.............78468
1068.230 CFR correction; (c)(1) and (2) removed....................38332
1090 Added.........................................................78469
Chapter V
1500--1508 (Subchapter A) Heading added............................43357
1500 Revised.......................................................43357
1501 Revised.......................................................43359
1502 Revised.......................................................43363
1503 Revised.......................................................43367
1504 Revised.......................................................43368
1505 Revised.......................................................43369
1506 Revised.......................................................43370
1507 Revised.......................................................43373
1508 Revised.......................................................43374
1515--1518 (Subchapter B) Heading added............................43376
Chapter VI
1604 Added.........................................................10094
Chapter VII
1700.3 Amended.....................................................43475
1700.15 Added......................................................43475
1700.19 Added......................................................43475
1700.20 Added......................................................43475
1700.24 Added......................................................43476
1700.26 Added......................................................43476
1700.27 Added......................................................43476
1700.28 Added......................................................43476
1700.34 Added......................................................43476
1700.35 Added......................................................43477
1700.36 Added......................................................43477
1700.37 Added......................................................43477

[[Page 816]]

                                  2021

40 CFR
                                                                   86 FR
                                                                    Page
Chapter I
1060.1 (a)(7), (c), and (d) revised; eff. 7-29-21..................34527
1060.5 (a)(1) revised; eff. 7-29-21................................34528
1060.30 Revised; eff. 7-29-21......................................34528
1060.104 (b)(3) revised; eff. 7-29-21..............................34528
1060.105 (c)(1) and (e) revised; eff. 7-29-21......................34528
1060.120 (b) and (c) revised; eff. 7-29-21.........................34528
1060.130 (b)(3) revised; eff. 7-29-21..............................34528
1060.135 Introductory text, (a), (b) introductory text, (2), (3), 
        and (4) revised; eff. 7-29-21..............................34529
1060.137 (a)(4) and (c)(1) revised; eff. 7-29-21...................34529
1060.205 (a) and (m) revised; eff. 7-29-21.........................34529
1060.225 (b) and (g) revised; (h) added; eff. 7-29-21..............34529
1060.230 (d)(2) revised; eff. 7-29-21..............................34529
1060.235 Heading, (d), and (e)(1) revised; (a) and (b) 
        redesignated as (b) and (a); eff. 7-29-21..................34529
1060.240 (e)(2)(i) revised; eff. 7-29-21...........................34530
1060.250 (a)(3)(ii) and (b) revised; eff. 7-29-21..................34530
1060.255 Revised; eff. 7-29-21.....................................34530
1060.501 (c) revised; eff. 7-29-21.................................34530
1060.505 (c)(3) revised; eff. 7-29-21..............................34531
1060.515 (a)(2) revised; eff. 7-29-21..............................34531
1060.520 (a), (b)(1), (4), (d)(3), (6), (8)(ii), (9), and (e) 
        revised; eff. 7-29-21......................................34531
1060.525 (a)(2) revised; eff. 7-29-21..............................34531
1060.601 (a) and (b)(2) revised; eff. 7-29-21......................34532
1060.610 Added; eff. 7-29-21.......................................34532
1060.640 Removed; eff. 7-29-21.....................................34532
1060.801 Amended; eff. 7-29-21.....................................34532
1060.810 (d) removed; (e) introductory text revised; eff. 7-29-21 
                                                                   34533
1060.815 Revised; eff. 7-29-21.....................................34533
1060.825 Revised; eff. 7-29-21.....................................34533
1065.1 (g) revised; eff. 7-29-21...................................34533
1065.2 (c) revised; eff. 7-29-21...................................34533
1065.130 (e) revised; eff. 7-29-21.................................34534
1065.140 (c)(6)(i) and (e)(2) revised; eff. 7-29-21................34534
1065.145 (e)(3)(i) revised; eff. 7-29-21...........................34534
1065.170 (a)(1) introductory text revised; eff. 7-29-21............34534
1065.205 Revised; eff. 7-29-21.....................................34534
1065.220 (a) introductory text revised; eff. 7-29-21...............34536
1065.225 (a) introductory text revised; eff. 7-29-21...............34536
1065.247 Revised; eff. 7-29-21.....................................34536
1065.260 (e) revised; eff. 7-29-21.................................34536
1065.266 (a) and (b) revised; eff. 7-29-21.........................34536
1065.275 (b)(2) revised; eff. 7-29-21..............................34536
1065.280 (a) revised; eff. 7-29-21.................................34536
1065.303 Revised; eff. 7-29-21.....................................34536
1065.307 Table 1 designated as (f); (c)(13), (d)(4), (6)(i), (7), 
        (9), (e)(3), (5), and new (f) revised; (e)(7)(i)(F), (G), 
        and (g) added; eff. 7-29-21................................34538
1065.309 (d)(2) revised; eff. 7-29-21..............................34541
1065.320 (b) removed; eff. 7-29-21.................................34541
1065.341 Revised; eff. 7-29-21.....................................34541
1065.342 (d)(2) revised; eff. 7-29-21..............................34543
1065.350 (d)(2) revised; eff. 7-29-21..............................34543
1065.355 (d)(2) revised; eff. 7-29-21..............................34543
1065.360 (a)(4) and (d)(12) added; eff. 7-29-21....................34543
1065.365 (a), (d), (f)(9), and (14) revised; eff. 7-29-21..........34543
1065.370 (e)(5) revised; eff. 7-29-21..............................34545
1065.375 (d)(2) revised; eff. 7-29-21..............................34545
1065.410 (c) and (d) revised; eff. 7-29-21.........................34545
1065.510 (a) introductory text, (b)(5)(i), and (f)(4)(i) revised; 
        (c)(5) added; eff. 7-29-21.................................34545
1065.512 (b)(1) and (2) revised; eff. 7-29-21......................34546
1065.514 (e) introductory text, (e)(3), and (f)(3) revised; eff. 
        7-29-21....................................................34546
1065.530 (a)(2)(iii) revised; (g)(5) added; eff. 7-29-21...........34546
1065.543 Added; eff. 7-29-21.......................................34547
1065.545 (a) and (b) introductory text revised; eff. 7-29-21.......34548

[[Page 817]]

1065.602 Revised; eff. 7-29-21.....................................34548
1065.610 (a)(1)(iv), (2) introductory text, and (d)(3) 
        introductory text revised; eff. 7-29-21....................34555
1065.640 (a), (b)(3), (d)(1), and (3) revised; eff. 7-29-21........34556
1065.642 (b) and (c)(1) revised; eff. 7-29-21......................34557
1065.643 Added; eff. 7-29-21.......................................34557
1065.650 (b)(3) introductory text, (c)(1), (2)(i) introductory 
        text, (3), (d) introductory text, (7), (f)(2) introductory 
        text, and (g) revised; eff. 7-29-21........................34560
1065.655 Heading, (a), (c) introductory text, (3), (d) 
        introductory text, (e), and (f)(3) revised; eff. 7-29-21 
                                                                   34563
1065.659 (c)(2) and (3) revised; eff. 7-29-21......................34566
1065.660 (a)(5) and (6) added; (b)(2) introductory text, (ii) 
        introductory text, (iii) introductory text, (3) 
        introductory text, (4), (c)(2), (d) introductory text, (1) 
        introductory text, (ii) introductory text, (iii) 
        introductory text, (2), and (e) revised; eff. 7-29-21......34566
1065.665 (a) revised; eff. 7-29-21.................................34567
1065.667 (d) revised; eff. 7-29-21.................................34567
1065.675 (d) revised; eff. 7-29-21.................................34568
1065.695 (c)(8)(v) added; eff. 7-29-21.............................34568
1065.701 (b) and (f) revised; eff. 7-29-21.........................34568
1065.703 (b) revised; eff. 7-29-21.................................34569
1065.705 (c) revised; eff. 7-29-21.................................34569
1065.710 (b)(2) and (c) revised; eff. 7-29-21......................34571
1065.715 (a) revised; eff. 7-29-21.................................34573
1065.720 (a) revised; eff. 7-29-21.................................34573
1065.750 (a)(1)(ii) revised; eff. 7-29-21..........................34574
1065.790 (b) revised; eff. 7-29-21.................................34574
1065.905 (f) revised; eff. 7-29-21.................................34574
1065.910 (a)(2) revised; eff. 7-29-21..............................34575
1065.915 (a) revised; eff. 7-29-21.................................34575
1065.1001 Amended; eff. 7-29-21....................................34575
1065.1005 (a), (c), (d), (e), (f)(2), and (g) revised; eff. 7-29-
        21.........................................................34575
1065.1010 (b) revised; eff. 7-29-21................................34579
1066.1 (g) revised; eff. 7-29-21...................................34581
1066.135 (a)(1) revised; eff. 7-29-21..............................34581
1066.210 (d)(3) revised; eff. 7-29-21..............................34581
1066.255 (c) revised; eff. 7-29-21.................................34581
1066.260 (c)(4) revised; eff. 7-29-21..............................34581
1066.265 (d)(1) revised; eff. 7-29-21..............................34581
1066.270 (c)(4) and (d)(2) revised; eff. 7-29-21...................34582
1066.275 (b) and (d) revised; eff. 7-29-21.........................34582
1066.405 Revised; eff. 7-29-21.....................................34582
1066.420 (d) revised; eff. 7-29-21.................................34582
1066.605 (c)(4) and (h)(2)(i) revised; eff. 7-29-21................34583
1066.610 (d) revised; eff. 7-29-21.................................34583
1066.710 (c) revised; eff. 7-29-21.................................34583
1066.801 (e) revised; eff. 7-29-21.................................34583
1066.835 (a) and (f)(2) revised; eff. 7-29-21......................34585
1066.930 Revised; eff. 7-29-21.....................................34585
1066.1005 (a), (c), (d), (e), and (f) revised; eff. 7-29-21........34585
1068.1 (a) amended; (d)(2) removed; eff. 7-29-21...................34588
1068.10 Heading, (b), and (c) revised; eff. 7-29-21................34589
1068.240 (b)(6), (c)(1), and (3) revised; eff. 7-29-21.............34589
1074.1--1074.12 (Subpart A) Appendix A amended; eff. 7-29-21.......34590
Chapter V
1507.3 (b) introductory text amended; interim......................34158
1519 Added..........................................................1280
1519 Removed.......................................................19151
Chapter IX
Chapter IX Added....................................................1287

                                  2022

40 CFR
                                                                   87 FR
                                                                    Page
Chapter I
1065.307 Correction: (c)(13), (e)(3), (v), and (vi) amended........64865
1065.530 Correction: (g)(5) amended................................64865
1065.543 Correction: (b)(1) and section amended....................64865
1065.602 Correction: (l)(1)(ii) and section amended................64865
1065.643 Correction: Amended.......................................64865
1065.650 Correction: Amended.......................................64865

[[Page 818]]

1065.655 Correction: Table 1 amended...............................64866
1065.1005 Correction: Table 1 amended..............................64866
1066.1005 Correction: Table 1 amended..............................64866
1090.15 (a), (c) introductory text, and (d) amended; (d) 
        redesignated as (e); new (d) added.........................39677
1090.285 (d) revised...............................................52484
Chapter V
1502 Authority citation revised....................................23469
1502.13 Revised....................................................23469
1507 Authority citation revised....................................23469
1507.3 (a) and (b) introductory text revised.......................23469
1508 Authority citation revised....................................23469
1508.1 (g) and (z) revised.........................................23469

                                  2023

   (Regulations published from January 1, 2023, through July 1, 2023)

40 CFR
                                                                   88 FR
                                                                    Page
Chapter I
1060.101 (e)(1) revised.............................................4669
1060.515 (c) and (d) revised........................................4669
1060.520 (b)(1) revised.............................................4669
1060.801 Amended....................................................4669
1065.1 (a)(1) through (5) and (8); (i) added........................4669
1065.5 (a) introductory text and (c) revised........................4669
1065.10 (c)(7)(ii) revised..........................................4670
1065.12 (a) revised.................................................4670
1065.140 (b)(2) introductory text, (c)(2), (6) introductory text, 
        and (e)(4) revised..........................................4670
1065.145 (b)(2) revised.............................................4670
1065.170 (a)(1), (c)(1)(ii), and (iii) revised......................4671
1065.190 (g)(5) and (6) removed.....................................4671
1065.210 (a) revised................................................4671
1065.260 (a) revised................................................4672
1065.274 Added......................................................4673
1065.284 Heading revised............................................4673
1065.298 Added......................................................4673
1065.301 (d) revised................................................4673
1065.305 (d)(10)(ii) revised........................................4673
1065.307 (b), (d) introductory text, and (f) revised................4673
1065.308 (e)(3) revised.............................................4674
1065.309 (e)(3) revised.............................................4674
1065.315 (a)(1) through (3) and (b) revised.........................4674
1065.320 (c) revised................................................4674
1065.325 (a) and (b) revised........................................4675
1065.330 (a) and (b) revised........................................4675
1065.341 (e)(3) revised.............................................4675
1065.345 (d) revised................................................4675
1065.350 (e)(1) revised.............................................4675
1065.405 (a) revised................................................4675
1065.410 (c) revised................................................4675
1065.501 (a) introductory text revised..............................4676
1065.510 (a) introductory text, (b) introductory text, (4) through 
        (6), (c)(2), (d) introductory text, (4), (5)(iii), and 
        (g)(2) revised..............................................4676
1065.512 (b)(1) revised.............................................4678
1065.514 (d) revised................................................4678
1065.530 (g)(5) introductory text revised...........................4679
1065.543 (a) and (b) revised........................................4679
1065.545 (a) and (b) introductory text revised......................4679
1065.610 Introductory text, (a) introductory text, (1) 
        introductory text, (b) introductory text, (1) introductory 
        text, (2), (3), and (c)(2) revised; (a)(4) removed..........4679
1065.630 (a) and (b) introductory text revised......................4680
1065.643 (d) revised................................................4680
1065.650 (a), (c)(2)(i), (3), (4)(i), (6), (d)(7), (e)(1), (2), 
        (f)(1), (2), (g)(1), and (2) revised........................4681
1065.655 (c) introductory text, (e)(1)(i), (4), and (f)(3) revised
                                                                    4684
1065.660 (b)(2)(i) introductory text, (c)(1), and (d)(1)(i) 
        introductory text revised...................................4686
1065.667 (a) revised................................................4686
1065.670 Introductory text revised..................................4686
1065.672 (d)(3) and (4) revised.....................................4686
1065.675 (b) revised................................................4686
1065.680 Introductory text revised..................................4686
1065.695 (a) and (c)(12)(ix) revised................................4687
1065.715 (b)(3) revised.............................................4687
1065.720 (a) and (b)(3) revised.....................................4687
1065.790 Revised....................................................4687
1065.901 (a) and (b)(3) revised.....................................4687

[[Page 819]]

1065.910 (b) and (d)(2) revised.....................................4688
1065.915 (d)(6) revised.............................................4688
1065.920 (b)(5) removed; (b)(6) and (7) redesignated as new (b)(5) 
        and (6); (b)(2), (4) introductory text, (iii), new (6)(ii) 
        revised.....................................................4688
1065.935 (d)(4) and (g) revised.....................................4688
1065.1001 Amended...................................................4689
1065.1005 Table 1 amended...........................................4689
1065.1010 Introductory text added; (a) removed; (b) through (g) 
        redesignated as new (a) through (f).........................4690
1065.1101--1065.1145 (Subpart L) Revised............................4691
1065.1113 Added.....................................................4691
1065.1115 Added.....................................................4691
1065.1117 Added.....................................................4691
1065.1119 Added.....................................................4691
1065.1121 Added.....................................................4691
1065.1123 Added...............................................4693, 4697
1065.1125 Added.....................................................4693
1065.1127 Added.....................................................4693
1066.110 (b)(1)(vi), (2)(i), and (2)(v) introductory text revised 
                                                                    4708
1066.220 (b) revised................................................4708
1066.301 (b) revised................................................4708
1066.415 (e)(2) revised.............................................4708
1066.420 (b) revised................................................4708
1066.710 Introductory text and (b)(1) revised; Figure 1 removed; 
        (f) added...................................................4708
1066.815 (d)(1)(ii) revised.........................................4709
1066.831 (d) revised................................................4709
1066.835 (f)(1), (2), and (3)(iii) revised..........................4709
1066.845 (c), (f)(3), and (g) revised; (h) added....................4710
1066.1001 Amended...................................................4710
1066.1005 (b), (g), and (h) revised.................................4710
1066.1010 Revised...................................................4711
1068.1 (a)(2), (4), (5), (6), (8), (9), and (13) revised; (a)(15) 
        added.......................................................4712
1068.10 Revised.....................................................4712
1068.11 Added.......................................................4713
1068.30 Amended.....................................................4714
1068.50 Added.......................................................4714
1068.101 (a) introductory text and (b)(5) revised...................4716
1068.210 (c) introductory text revised..............................4716
1068.220 (b) revised................................................4716
1068.240 (a)(1), (b)(3), and (c)(3)(ii) revised.....................4716
1068.261 (b), (c) introductory text, and (d) introductory text 
        revised.....................................................4716
1068.301 (b) revised................................................4716
1068.310 (e)(4) introductory text revised...........................4717
1068.315 (a) and (h) revised; (i) removed...........................4717
1068.325 Introductory text, (a) through (c), (e), and (g) revised 
                                                                    4717
1068.450 (e) revised................................................4718
1068.601 Introductory text and (b) revised..........................4718
1068.630 Added......................................................4718
1068 Appendix I, Appendix II, and Appendix III amended..............4718
1090.1550 Revised...................................................4718
Chapter VI
1600.2 (b) revised.................................................36256
1600.4 (e) added...................................................36256
1600.5 (a), (b), (c)(1)(i), and (ii) revised; (c)(1)(iii) removed 
                                                                   36256
1600.6 Revised.....................................................36257


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